Well Flow Control Systems and Methods

ABSTRACT

Flow control systems and methods for use in hydrocarbon well operations include a tubular and a flow control apparatus. The tubular defines a well annulus and includes an outer member defining a flow conduit. Fluid communication between the well annulus and the flow conduit is provided by permeable portion(s) of the outer member. The flow control apparatus is disposed within the flow conduit and comprises conduit-defining and chamber-defining structural members. The conduit-defining structural member(s) is configured to divide the flow conduit into at least two flow control conduits. The chamber-defining structural member(s) is configured to divide at least one of the at least two flow control conduits into at least two flow control chambers. Each of the flow control chambers has at least one inlet and one outlet, each of which is adapted to allow fluid flow therethrough and to retain particles larger than a predetermined size.

FIELD

The present disclosure relates generally to systems and methods forrecovering hydrocarbons from subsurface reservoirs. More particularly,the present disclosure relates to systems and methods for controllingthe flow of undesired particulates from subsurface reservoirs throughwell equipment to the surface.

BACKGROUND

This section is intended to introduce the reader to various aspects ofart, which may be associated with embodiments of the present invention.This discussion is believed to be helpful in providing the reader withinformation to facilitate a better understanding of particulartechniques of the present invention. Accordingly, it should beunderstood that these statements are to be read in this light, and notnecessarily as admissions of prior art.

Hydrocarbon production from subterranean reservoirs commonly includes awell completed in either a cased-hole or an open-hole condition. Incased-hole applications, a well casing is placed in the well and theannulus between the casing and the well is filled with cement.Perforations are made through the casing and the cement into theproduction zones to allow formation fluids (such as, hydrocarbons) toflow from the production zones into the conduit within the casing.Additionally or alternatively, the fluid flow may be from the conduitwithin the casing into the subterranean formation, such as duringinjection operations. While the discussion herein will generally referto production operations and fluid flow in the production direction, theprinciples and technologies described herein apply by analogy to fluidflow in the injection direction. A production string (or, an injectionstring), consisting primarily of one or more tubulars, is then placedinside the casing, creating an annulus between the casing and theproduction string. Formation fluids flow into the annulus and then intothe production string to the surface through tubulars associated withthe production string. In open-hole applications, the production stringis directly placed inside the well without casing or cement. Formationfluids flow into the annulus between the formation and the productionstring and then into the production string to surface.

Modern hydrocarbon wells generally pass through or into multiplesubterranean formation types and are continually reaching ever greaterdepths and/or lengths (such as for extended reach horizontal wells).Additionally, it is common for hydrocarbon wells to extend throughmultiple reservoirs over the life of the well. In some implementations,the well may extend through multiple reservoirs during any givenproduction operation. Additionally or alternatively, a well may extendthough a single reservoir that operates more like multiple reservoirsdue to the variations of formation properties within the reservoirand/or the size of the reservoir.

The ever increasing complexity of modern hydrocarbon productionoperations often necessitates increasingly complex well constructionsand completions. The construction of a hydrocarbon well typicallyincludes modeling the subsurface to estimate the formation and reservoirproperties. The modeling typically includes inputs from geologic andseismic data as well as data from test wells and/or adjacent wells inthe field. These modeling efforts enable the scientists and engineers toidentify a preferred location for the well and preferred drillingparameters for the drilling of the well. For example, the rate ofpenetration, the mud weight, and several parameters related to thedrilling operation can affect the long-term operation of the well. Whilethe models and the technology underlying the models are continuallyevolving, the scientists and engineers are left with an approximationbased on previously collected data. The drilling operation is a dynamic,multi-parameter operation where changes in any one parameter couldimpact any of several parameters over the life of the well.

While the drilling plan can have significant impact on the operation ofthe well during its life, the completion of the well is often considereddeterminative of how a given well, once drilled, will operate. As usedherein, completion is used generically to refer to procedures andequipment designed to allow a well to be operated safely andefficiently. The point at which the completion process begins may dependon the type and design of well. However, there are many options appliedor actions performed during the construction phase of a well that havesignificant impact on the productivity of the well. Accordingly,completion plans are often prepared prior to the drilling operationsbased on the models and collected data. The completion plans are oftenupdated based on data collected during the drilling operations tofurther optimize the operation of the well (whether injection orproduction).

Despite the accuracy or completeness of the data available when thecompletion plan is finalized and the completion is implemented in thewell, the well's evolution, the reservoir's evolution, and theformation's evolution during the life of the well make most completionsinadequate for the extended life of the well. Accordingly, sophisticatedwork-over procedures have been developed to allow operators to changethe completion of a well after production and/or injection operationshave begun. Additionally, several efforts have been made to developintelligent or flexible completions that can be changed during the lifeof the well without requiring the withdrawal of the completion equipmentfrom the well. Many of these intelligent completions require mechanicalequipment downhole that is controlled from the surface between two ormore configurations. While the adaptable completion concept is sound,the harsh conditions of the well and the long life of the well generallycomplicate efforts to manipulate these multi-configuration mechanicaldevices deep in the well. Moreover, the requirement of these systems tobe activated from the surface creates a time delay while the results ofthe changed downhole condition increasingly manifests itself at thesurface and is observed at the surface, and then the control signal canbe sent to the downhole equipment that has to transition betweenconfigurations.

When producing fluids from subterranean formations, especially poorlyconsolidated formations or formations weakened by increasing downholestress due to well excavation and fluids withdrawal, it is possible toproduce solid material (for example, sand) along with the formationfluids. This solids production may reduce well productivity, damagesubsurface equipment, and add handling cost on the surface. Controllingthe production of solids or particles is one example of the objectivesof the completion equipment and procedures. Several downhole solid,particularly sand, control methods are currently being practiced by theindustry and are shown in FIGS. 1( a), 1(b), 1(c) and 1(d). In FIG. 1(a), the production string or pipe (not shown) typically includes a sandscreen or sand control device 1 around its outer periphery, which isplaced adjacent to each production zone. The sand screen prevents theflow of sand from the production zone 2 into the production string (notshown) inside the sand screen 1. Slotted or perforated liners can alsobe utilized as sand screens or sand control devices. FIG. 1( a) is anexample of a screen-only completion with no gravel pack present.

One of the most commonly used techniques for controlling sand productionis gravel packing in which sand or other particulate matter is depositedaround the production string or well screen to create a downhole filter.FIGS. 1( b) and 1(c) are examples of cased-hole and open-hole gravelpacks, respectively. FIG. 1( b) illustrates the gravel pack 3 outsidethe screen 1, the well casing 5 surrounding the gravel pack 3, andcement 8 around the well casing 5. Typically, perforations 7 are shotthrough the well casing 5 and cement 8 into the production zone 2 of thesubterranean formations around the well. FIG. 1( c) illustrates anopen-hole gravel pack wherein the well has no casing and the gravel packmaterial 3 is deposited around the well sand screen 1.

A variation of a gravel pack involves pumping the gravel slurry atpressures high enough so as to exceed the formation fracture pressure(frac pack). FIG. 1( d) is an example of a Frac-Pack. The well screen 1is surrounded by a gravel pack 3, which is contained by a well casing 5and cement 8. Perforations 6 in the well casing allow gravel to bedistributed outside the well to the desired interval. The number andplacement of perforations are chosen to facilitate effectivedistribution of the gravel packing outside the well casing to theinterval that is being treated with the gravel-slurry.

Flow impairment during production from subterranean formations canresult in a reduction in well productivity or complete cessation of wellproduction. This loss of functionality may occur for a number ofreasons, including but not limited to: 1) migration of fines, shales, orformation sands; 2) inflow or coning of unwanted fluids (such as, wateror gas); 3) formation of inorganic or organic scales; 4) creation ofemulsions or sludges; 5) accumulation of drilling debris (such as, mudadditives and filter cake); 6) excessive inflow of particles, such assand, into and through the production tubulars due to mechanical damageto sand control screen and/or due to incomplete or ineffective gravelpack implementations; 7) and mechanical failure due to boreholecollapse, reservoir compaction/subsidence, or other geomechanicalmovements.

There are several examples of technology that has been developed inefforts to address these problems. Examples of such technologies can befound in numerous U.S. patents, including those mentioned briefly here.For example, U.S. Pat. No. 6,622,794 discloses a screen equipped with aflow control device, which includes multiple apertures and channels todirect and restrict flow. The fluid flow through the screen is disclosedas being reduced by controlling downhole apertures from the surfacebetween fully opened and completely closed positions. U.S. Pat. No.6,619,397 discloses a tool for zone isolation and flow control inhorizontal wells. The tool is composed of blank base pipes, screens withcloseable ports on the base pipe, and conventional screens positioned inan alternating manner. The closeable ports allow complete gravel packover the blank base pipe section, flow shutoff for zone isolation, andselective flow control. U.S. Pat. No. 5,896,928 discloses a flow controldevice placed downhole with or without a screen. The device has alabyrinth which provides a tortuous flow path or helical restriction.The level of restriction in each labyrinth is controlled from thesurface by adjusting a sliding sleeve so that flow from each perforatedzone (for example, water zone, oil zone) can be controlled. U.S. Pat.No. 5,642,781 discloses a well screen jacket composed of overlappedmembers wherein the openings allow fluid flow through alternatecontraction, expansion and provide fluid flow direction change in thewell (or multi-passage). Such design may mitigate solids plugging ofscreen jacket openings by establishing both filtering and fluid flowmomentum advantages.

Numerous other examples can be identified. However, current industrywell designs and completions plans include little, if any, redundancy inthe event of problems or failures resulting in flow impairment. In manyinstances, the ability of a well to produce at or near its designcapacity is sustained by only a “single” barrier to the impairmentmechanism (for example, a single screen for ensuring sand control). Inmany instances, the utility of the well may be compromised by impairmentoccurring in the single barrier. As indicated above, flow impairment mayoccur by a variety of mechanisms and various efforts have been made toaddress these mechanisms, including efforts to provide redundantbarriers to the impairment mechanism. However, the systems currentlyavailable fail to provide a system that provides redundancy in theprevention of two or more impairment mechanisms. For example, preventionof impairment mechanisms such as particulate inflow and particulateblockages. Therefore, overall system reliability of the presentlyavailable systems is low. Accordingly, there is a need for wellcompletion equipment and methods to provide multiple flow pathwaysinside the well that provides redundant flow pathways in the event ofparticulate blockage, particulate inflow, or other forms of impairment.

SUMMARY

The present disclosure is directed to systems and methods forcontrolling fluid flow in well equipment associated with hydrocarbonwells An exemplary well flow control system includes a tubular and aflow control apparatus. The tubular is adapted to be disposed in a wellto define a well annulus. The tubular has an outer member defining aninternal flow conduit and at least a portion of the outer member ispermeable allowing fluid communication between the well annulus and theflow conduit. The flow control apparatus is adapted to be disposedwithin the flow conduit of the tubular. The flow control apparatuscomprises at least one conduit-defining structural member and at leastone chamber-defining structural member. The at least oneconduit-defining structural member is configured to divide the flowconduit into at least two flow control conduits. The at least onechamber-defining structural members is configured to divide at least oneof the at least two flow control conduits into at least two flow controlchambers. Each of the at least two flow control chambers has at leastone inlet and at least one outlet. Each of the at least one inlet andthe at least one outlet is adapted to allow fluids to flow therethroughand to retain particles larger than a predetermined size.

Implementations of flow control systems within the scope of the presentinvention may include several variations on the features describedabove. For example, fluid flow through an outlet of a flow controlchamber formed in a first flow control conduit may pass into a secondflow control conduit. Additionally or alternatively, the retention ofparticles larger than a predetermined size by the outlet mayprogressively increase resistance to flow through the outlet from theflow control chamber until fluid flow through the outlet is at leastsubstantially blocked. In some implementations, the at least two flowcontrol chambers may be disposed within the flow conduit of the tubularsuch that fluid flow entering through the permeable portion of the outermember passes into at least one flow control chamber. For example, theat least one inlet to the flow control chamber is provided by thepermeable portion of the outer member of the tubular.

In some implementations, the at least one inlet to the flow controlchamber may be adapted to retain particles of a first predetermined sizeand the at least one outlet from the flow control chamber may be adaptedto retain particles of a second predetermined size. Additionally oralternatively, the at least one inlet and the at least one outlet of theflow control chamber are adapted to retain particles having at leastsubstantially similar predetermined sizes. For example, the flow controlchamber may be adapted to progressively retain particles larger than thepredetermined size of the at least one outlet in the event that the atleast one inlet is impaired. In some implementations, the at least oneinlet and the at least one outlet for at least one of the flow controlchambers may be fluidically offset and in fluid communication.

In some implementations of the present flow control systems, the flowwithin at least one of the flow control chambers may be at leastsubstantially longitudinal and the at least one chamber-definingstructural member may be disposed at least substantially transverse tothe longitudinal direction. Additionally or alternatively, the flowwithin at least one of the flow control chambers may be at leastsubstantially circumferential and the at least one chamber-definingstructural member may be disposed at least substantially transverse tothe circumferential direction. Still additionally or alternatively, theflow within at least one of the flow control chambers may be at leastsubstantially radial and the at least one chamber-defining structuralmember may be disposed at least substantially transverse to the radialdirection.

Exemplary implementations of the flow control apparatus may include atleast one conduit-defining structural member provided by an innertubular having permeable segments and impermeable segments. The innertubular defines a first flow control conduit within the inner tubularand a second flow control conduit between the outer member and the innertubular. The at least one chamber-defining structural member and the atleast two flow control chambers are disposed in the second flow controlconduit. Additionally or alternatively, the at least oneconduit-defining structural member may be adapted to divide the flowconduit into at least three flow control conduits. In someimplementations, the chamber-defining structural members may define flowcontrol chambers in at least two of the at least three flow controlconduits. In such implementations, at least one of the at least threeflow control conduits may be in fluid communication with the wellannulus only through one or more of the flow control chambers. Inimplementations having flow control chambers in two or more flow controlconduits, the flow control chambers in adjacent flow control conduitsmay be fluidically offset and in fluid communication.

Implementations of the present flow control systems may include at leastone conduit-defining structural member comprising an inner tubularhaving permeable segments and impermeable segments. The inner tubularmay define a first flow control conduit within the inner tubular. The atleast one conduit-defining structural member further comprises helicallywrapped flights extending along at least a portion of the inner tubularand configured to define at least one helical flow control conduitbetween the outer member and the inner tubular. In such implementations,the at least one chamber-defining structural member and the at least twoflow control chambers may be disposed in the at least one helical flowcontrol conduit.

Additionally or alternatively, one or more of the at least one outletsmay be adapted to be selectively opened to control fluid flow throughthe outlet. In some implementations, at least one of the at least twoflow control chambers may include at least two outlets adapted to retainparticles of different predetermined sizes. In such implementations,each of the at least two outlets may adapted to be selectively opened tofluid flow to selectively retain particles of different predeterminedsizes depending on which outlet is opened.

The inlet to at least one flow control chamber may be formed in the flowcontrol apparatus and the outlet from the at least one flow controlchamber may be formed by the permeable portion of the outer member.Additionally or alternatively, the permeable portion of the outer membermay provide an inlet to at least one flow control chamber and the outletfrom the at least one flow control chamber may be formed in the flowcontrol apparatus.

The present disclosure is further directed to a flow control apparatusadapted for insertion into a flow conduit of a well tubular. Exemplaryflow control apparatus include at least one conduit-defining structuralmember and at least one chamber-defining structural member. The at leastone conduit-defining structural member may be adapted to be inserted ina flow conduit of a well tubular and to divide the flow conduit into atleast two flow control conduits. The at least one chamber-definingstructural member may be configured to divide at least one of the atleast two flow control conduits into at least two flow control chambers.The flow control apparatus further includes at least one permeableregion provided in at least one of the at least one conduit-definingstructural member and the at least one chamber-defining structuralmember. The at least one permeable region is adapted to allow fluidcommunication and to retain particles larger than a predetermined size.The permeable portion is provided such that fluids flowing through theat least one permeable region passes from a first flow control conduitto a second flow control conduit within the flow conduit.

Flow control apparatus within the scope of the present invention mayinclude variations on the components described above and/or features inaddition to those described above. For example, some implementations mayinclude swellable materials disposed at least on the at least oneconduit-defining structural member and adapted to at least substantiallyseal against the well tubular to fluidically isolate the at least twoflow control conduits from each other such that flow between flowcontrol conduits occurs at least substantially only through the at leastone permeable region. Additionally or alternatively, at least twopermeable regions may be provided from at least one flow controlchamber. In some implementations, the at least two permeable regions maybe adapted to retain particles of different predetermined sizes.Additionally or alternatively, some implementations of the present flowcontrol apparatus may include at least one permeable region adapted tobe selectively opened to control the particle size being filtered fromthe flow through the permeable region.

Some implementations may include at least one conduit-definingstructural member provided by an inner tubular having permeable segmentsand impermeable segments. The inner tubular may defines a first flowcontrol conduit within the inner tubular and a second flow controlconduit outside of the inner tubular. The at least one chamber-definingstructural member and the at least two flow control chambers may bedisposed in the second flow control conduit. Additionally oralternatively, the at least one conduit-defining structural member maybe adapted to divide the flow conduit into at least three flow controlconduits. In some implementations having at least three flow controlconduits the at least one chamber-defining structural member may defineflow control chambers in at least two of the at least three flow controlconduits. Additionally or alternatively, in implementations having flowcontrol chambers in two or more flow control conduits, the flow controlchambers in adjacent flow control conduits may be fluidically offset andin fluid communication.

Still additional or alternative implementations include at least oneconduit-defining structural member comprising an inner tubular havingpermeable segments and impermeable segments. The inner tubular defines afirst flow control conduit within the inner tubular. The at least oneconduit-defining structural member may further comprise helicallywrapped flights extending along at least a portion of the inner tubularand configured to define at least one helical flow control conduitoutside of the inner tubular. In such implementations, the at least onechamber-defining structural member and the at least two flow controlchambers may be disposed in the at least one helical flow controlconduit.

The present disclosure is further directed to methods of controllingparticulate flow in hydrocarbon well equipment. The methods includeproviding a tubular adapted for downhole use in a well. The tubularcomprises an outer member defining a flow conduit and at least a portionof the outer member is permeable and allows fluid flow through the outermember. The methods further include providing at least one flow controlapparatus comprising: a) at least one conduit-defining structural memberadapted to be disposed in the flow conduit of the tubular and to dividethe flow conduit into at least two flow control conduits; and b) atleast one chamber-defining structural member configured to divide atleast one of the at least two flow control conduits into at least twoflow control chambers. The methods further include disposing the tubularin a well, disposing the at least one flow control apparatus in thewell, and operatively coupling the at least one flow control apparatuswith the tubular. The foregoing steps of providing, disposing, andcoupling may occur in any suitable order such that the assembled tubularand flow control apparatus is disposed in a well. The operativelycoupled tubular and at least one flow control apparatus together providethe at least two flow control conduits and the at least two flow controlchambers. Moreover, each of the at least two flow control chambers hasat least one inlet and at least one outlet and each of the at least oneinlet and the at least one outlet is adapted to allow fluids to flowtherethrough and to retain particles larger than a predetermined size.The methods further include flowing fluids through the at least one flowcontrol apparatus and the tubular.

Similar to the above descriptions of the flow control systems andapparatus, the present flow control methods may include numerousvariations and/or adaptations depending on the conditions in which themethods are implemented. For example, in some implementations, thepermeable portion of the outer member may provide at least one inlet toat least one flow control chamber and the step of flowing fluids throughthe at least one flow control apparatus and the tubular may includeflowing production fluids through the permeable portion of the outermember and through the outlets of the flow control chambers to producehydrocarbons from the well.

Additionally or alternatively, the step of flowing fluids through the atleast one flow control apparatus and the tubular may include: 1) flowingfluid into at least one flow control chamber disposed in a first flowcontrol conduit through at least one inlet, wherein the fluid flowsthrough the at least one inlet in a first flow direction; 2) redirectingthe fluid within the flow control chamber to flow in a second flowdirection; and 3) redirecting the fluid within the flow control chamberto flow in a third flow direction to pass through the at least oneoutlet and into a second flow control conduit. In some implementations,the second flow direction may be at least substantially longitudinal.Additionally or alternatively, the second flow direction may be at leastsubstantially circumferential, at least substantially radial, and/or atleast substantially helical.

Still additionally or alternatively, the step of flowing fluids throughthe at least one flow control apparatus and the tubular may compriseinjecting fluids into the well. Additionally or alternatively, flowingfluids through the at least one flow control apparatus and the tubularmay comprise injecting completion fluids into the well. Flowing fluidsthrough the at least one flow control apparatus and the tubular mayadditionally or alternatively comprise injecting gravel packcompositions into the well.

BRIEF DESCRIPTION OF THE DRAWINGS

The foregoing and other advantages of the present technique may becomeapparent upon reading the following detailed description and uponreference to the drawings in which:

FIGS. 1A-1D are schematic illustrations of conventional sand controltechnologies;

FIG. 2 is a schematic view of a well providing a context for someimplementations of the present technology;

FIG. 3 is a representative flow chart of methods according to thepresent technology;

FIG. 4 is a partial cut-away view of a well incorporatingimplementations of the present technology;

FIGS. 5A and 5B are partial cut-away views of a flow control systemaccording to the present technology in a first operational condition anda second operational condition, respectively;

FIGS. 6A-6C are schematic side views presenting operational flowdiagrams of some implementations of the present technology, with eachfigure representing different operational conditions;

FIGS. 6D-6F are schematic side views presenting operational flowdiagrams of some implementations of the present technology, with eachfigure representing different operational conditions;

FIG. 7A is a cross-sectional end view of a trifurcated configuration ofthe present technology;

FIG. 7B is a cross-sectional end view of a coaxial-furcatedconfiguration of the present technology;

FIG. 8A is a cross-sectional side view of a coaxial-furcatedconfiguration of the present technology;

FIGS. 8B-8D are cross-sectional views of the implementation illustratedin FIG. 8A at the indicated locations;

FIG. 9A is a cross-sectional side view of a coaxial-furcatedconfiguration of the present technology including injection conduits;

FIGS. 9B-9D are cross-sectional views of the implementation illustratedin FIG. 9A at the indicated locations;

FIG. 10A is a partial cutaway side view of an eccentric configuration ofthe present technology;

FIG. 10B is a cross-sectional view of the configuration illustrated inFIG. 10A;

FIGS. 11A and 11B are partial cut-away views of a flow control systemaccording to the present technology in a first operational condition anda second operational condition, respectively.

DETAILED DESCRIPTION

In the following detailed description, specific aspects and features ofthe present invention are described in connection with severalembodiments. However, to the extent that the following description isspecific to a particular embodiment or a particular use of the presenttechniques, it is intended to be illustrative only and merely provides aconcise description of exemplary embodiments. Moreover, in the eventthat a particular aspect or feature is described in connection with aparticular embodiment, such aspects and features may be found and/orimplemented with other embodiments of the present invention whereappropriate. Accordingly, the invention is not limited to the specificembodiments described below, but rather; the invention includes allalternatives, modifications, and equivalents falling within the scope ofthe appended claims.

As described above, completion systems and procedures are implemented inhydrocarbon wells in an effort to control flows through the downholeequipment and to promote efficient operation of the wells. Due to thevariety of conditions under which wells are operated, it is impossibleto sufficiently illustrate or capture the multitude of manners in whichthe present technology can be implemented. However, it should beunderstood that the technologies of the present disclosure may beimplemented in production and/or injection wells, may be implemented invertical wells, deviated wells, and/or horizontal wells, may beimplemented in deep water wells, extended reach wells, arctic wells, andland-based wells, may be implemented in gas wells and in oil wells, andin virtually any other type of well and well operation that may beimplemented in connection with the production of hydrocarbons. Theconfigurations and implementations described herein are merely exemplaryof the manners in which the technologies of the present disclosure maybe used.

Turning now to the drawings, and referring initially to FIG. 2, anexemplary production system 100 in accordance with certain aspects ofthe present disclosure is illustrated. In the exemplary productionsystem 100, a floating production facility 102 is coupled to a subseatree 104 located on the sea floor 106. Through this subsea tree 104, thefloating production facility 102 accesses one or more subsurfaceformations, such as subsurface formation 107, which may include multipleproduction intervals or zones 108 a-108 n, wherein number “n” is anyinteger number. The distinct production intervals 108 a-108 n maycorrespond to distinct reservoirs and/or to distinct formation typesencompassed by a common reservoir. The production intervals 108 a-108 ncorrespond to regions or intervals of the formation having hydrocarbons(e.g., oil and/or gas) to be produced or otherwise acted upon (such ashaving fluids injected into the interval to move the hydrocarbons towarda nearby well, in which case the interval may be referred to as aninjection interval). While FIG. 2 illustrates a floating productionfacility 102, it should be noted that the production system 100 isillustrated for exemplary purposes and implementations of the presenttechnologies may be useful in the production or injection of fluids fromany subsea, platform or land location.

The floating production facility 102 may be configured to monitor andproduce hydrocarbons from the production intervals 108 a-108 n of thesubsurface formation 107. The floating production facility 102 may be afloating vessel capable of managing the production of fluids, such ashydrocarbons, from subsea wells. These fluids may be stored on thefloating production facility 102 and/or provided to tankers (not shown).To access the production intervals 108 a-108 n, the floating productionfacility 102 is coupled to a subsea tree 104 and control valve 110 via acontrol umbilical 112. The control umbilical 112 may include productiontubing for providing hydrocarbons from the subsea tree 104 to thefloating production facility 102, control tubing for hydraulic orelectrical devices, and/or a control cable for communicating with otherdevices within the well 114.

To access the production intervals 108 a-108 n, the well 114 penetratesthe sea floor 106 to a depth that interfaces with the productionintervals 108 a-108 n at different depths (or lengths in the case ofhorizontal or deviated wells) within the well 114. As may beappreciated, the production intervals 108 a-108 n, which may be referredto as production intervals 108, may include various layers or intervalsof rock that may or may not include hydrocarbons and may be referred toas zones. The subsea tree 104, which is positioned over the well 114 atthe sea floor 106, provides an interface between devices within the well114 and the floating production facility 102. Accordingly, the subseatree 104 may be coupled to a production tubing string 128 to providefluid flow paths and a control cable (not shown) to providecommunication paths, which may interface with the control umbilical 112at the subsea tree 104.

Within the well 114, the production system 100 may also includedifferent equipment to provide access to the production intervals 108a-108 n. For instance, a surface casing string 124 may be installed fromthe sea floor 106 to a location at a specific depth beneath the seafloor 106. Within the surface casing string 124, an intermediate orproduction casing string 126, which may extend down to a depth near theproduction interval 108 a, may be utilized to provide support for wallsof the well 114. The surface and production casing strings 124 and 126may be cemented into a fixed position within the well 114 to furtherstabilize the well 114. Within the surface and production casing strings124 and 126, a production tubing string 128 may be utilized to provide aflow path through the well 114 for hydrocarbons and other fluids. Asubsurface safety valve 132 may be utilized to block the flow of fluidsfrom portions of the production tubing string 128 in the event ofrupture or break above the subsurface safety valve 132. Further, packers134-136 may be utilized to isolate specific zones within the wellannulus from each other. The packers 134-136 may be configured toprovide fluid communication paths between surface and the sand controldevices 138 a-138 n, while preventing fluid flow in one or more otherareas, such as a well annulus.

In addition to the above equipment, other equipment, such as sandcontrol devices 138 a-138 n and gravel packs 140 a-140 n, may beutilized to manage the flow of fluids from within the well. Inparticular, the sand control devices 138 a-138 n together with thegravel packs 140 a-140 n may be utilized to manage the flow of fluidsand/or particles into the production tubing string 128. The sand controldevices 138 a-138 n may include slotted liners, stand-alone screens(SAS); pre-packed screens; wire-wrapped screens, membrane screens,expandable screens and/or wire-mesh screens, while the gravel packs 140a-140 n may include gravel or other suitable solid material. The sandcontrol devices 138 a-138 n may also include inflow control mechanisms,such as inflow control devices (i.e. valves, conduits, nozzles, or anyother suitable mechanisms), which may increase pressure loss along thefluid flow path. The gravel packs 140 a-140 n may be complete gravelpacks that cover all of the respective sand control devices 138 a-138 n,or may be partially disposed around sand control devices 138 a-138 n.The sand control devices 138 a-138 n may include different components orconfigurations for any two or more of the intervals 108 a-108 n of thewell to accommodate varying conditions along the length of the well. Forexample, the intervals 108 a-108 b may include a cased-hole completionand a particular configuration of sand control devices 138 a-138 b whileinterval 108 n may be an open-hole interval of the well having adifferent configuration for the sand control device 138 n.

Conventionally, packers or other flow control mechanisms are disposedbetween adjacent intervals 108 to enable production in each of the zonesto be independently controlled. For example, sand production into theannulus of interval 108 b would be isolated to interval 108 b by packers135. FIG. 2 schematically illustrates wells 114 and particularlyintervals 108 within wells are not uniform and that the reservoirs andformations come in a variety of configurations that are not easilyadaptable to zonal isolation through packers. As an example, intervals108 c and 108 d are schematically illustrated as adjoining in FIG. 2 andillustrated as not including a packer disposed therebetween. Adjoiningintervals is one example of circumstances where zonal isolation throughconventional packers is not practical. Additional examples, includewells traversing excessive numbers of different formations and/or zonessuch that the number of required packers would not be economicallypractical; wells traversing formations where the properties of theformations change gradually, yet substantially, such that the gradationscan not be economically partitioned through conventional packers; andvarious other circumstances where the costs and/or operational risksassociated with packer installation render the use of a packerimpractical. As yet another example of well conditions where zonalisolation through conventional packer technology is not feasible, theconditions in each of the intervals 108 are dynamic during the operationof the well and what was initially considered to be operably a singleinterval may evolve to where the most efficient operation of the wellwould be to isolate the single interval into multiple intervals or zonesfor independent control. The changing characterization of an interval torequire its partitioning into multiple intervals is common in welloperations and is commonly accomplished through expensive andoperationally risky workover procedures.

The technologies of the present disclosure are adapted to be disposed ina well to provide a flow control apparatus in association with adownhole tubular to provide redundant impairment resolution systems.FIG. 3 provides a schematic flow diagram 200 of methods within the scopeof the present disclosure and invention. The methods of FIG. 3 beginwith providing a tubular adapted for downhole use, denoted as block 210.At block 212, the method continues by providing a flow controlapparatus, such as those that will be described herein. FIG. 3illustrates that the methods of the present disclosure may beimplemented in a variety of orders or sequences of steps depending onthe condition of the well in which the technologies herein will be used.For example, in a new well or in a well from which the production tubinghas been removed, the method 200 may include operatively associating theflow control apparatus with the tubular, at 214, followed by disposingthe combined tubular and flow control apparatus in the well, such asillustrated at 216. Additionally or alternatively, the methods 200 ofthe present disclosure may include disposing the tubular in a well,denoted as block 218. The tubular may be disposed in the well before theflow control apparatus is provided, such as when the flow controlapparatus is being installed in an existing production tubular.Alternatively, the tubular may be disposed in the well prior toassociating the flow control apparatus with the tubular for otherreasons. FIG. 3 illustrates at 220 that the flow control apparatus maybe operatively associated with a tubular that is already disposed in awell.

The steps 210-220 of the present methods may be implemented in anysuitable order or sequence so as to eventually have a flow controlapparatus operatively associated with a tubular and disposed in a well.For example, the provision of the tubular may occur many years beforethe provision of the flow control apparatus. Similarly, the tubular maybe disposed in a well long before the flow control apparatus isprovided. The schematic flow chart of FIG. 3 illustrates just two of themany routes possible for arriving at the operative condition of having aflow control apparatus associated with a tubular and disposed in a well,all of which are within the scope of the present methods.

Once the flow control apparatus is disposed in the well and associatedwith a tubular, the methods 200 continue at 222 by flowing fluidsthrough the flow control apparatus and the tubular. As indicated above,the fluid flow may be in the production direction (e.g., fluids flowthrough the tubular then through the flow control apparatus) or in theinjection direction (e.g., fluids flow through the flow controlapparatus then through the tubular), both being within the scope of thepresent methods. Finally, methods 200 produce hydrocarbons, such asindicated at 224, which hydrocarbons may be produced from the well inwhich the flow control apparatus is disposed or from associated wells(such as when the flow control apparatus is used in injection wells).

The discussion herein of the present systems and methods primarilydescribes the components and features in a production context. Forexample, flow control conduits and chambers are described below ashaving inlets and outlets associated with structural members, whichinlets and outlets may be context specific. For example, a permeableportion of a structural member may provide an outlet in a productionoperation context and may provide an inlet in an injection operationcontext. Similarly, the production-centric discussion herein describesfeatures and aspects configured to prevent sand or particles fromentering a production conduit in communication with the surface. Byanalogy, each and all of the implementations described herein and/orthose within the scope of the present invention may have labels andnomenclature suitable adapted for the injection operations. For example,in an injection operation the well annulus is the conduit in directcommunication with the target (i.e., the formation) in the same mannerthat the production conduit is in direct communication with the targetin the production operation (i.e., the surface).

Accordingly, while many of the implementations described herein includenomenclature and/or descriptions written in the production context, thepresent invention is not so limited. Adaptations of the presentimplementations for use in injection operations typically involvenothing more than changing the nomenclature used to refer to thecomponents. In some implementations, the precise disposition of acomponent may change in an injection operation. However, the relativedisposition of elements or components will remain with the scope of theprinciples and implementations described herein. More specifically, theflow control systems within the present disclosure, whether used inproduction operations, injection operations, treatment operations, orotherwise, include a tubular and a flow control apparatus. The tubulardefines a well annulus outside thereof and includes an outer memberdefining a flow conduit within the outer member. At least a portion ofthe outer member is permeable providing fluid communication between thewell annulus and the flow conduit. The flow control apparatus isdisposed within the flow conduit and comprises at least oneconduit-defining structural member and at least one chamber-definingstructural member. The at least one conduit-defining structural memberis configured to divide the flow conduit into at least two flow controlconduits. The at least one chamber-defining structural member isconfigured to divide at least one of the at least two flow controlconduits into at least two flow control chambers. Each of the at leasttwo flow control chambers has at least one inlet and one outlet, each ofwhich is adapted to allow fluids to flow therethrough and to retainparticles larger than a predetermined size.

FIG. 4 illustrates a section 240 of a well 242 in a formation 244. Thewell section 240 is illustrated as being a vertical section of the well242, but is illustrated here as merely exemplary as the technology maybe used in vertical, horizontal, or otherwise oriented wells. Asillustrated in FIG. 4, the well 242 includes flow control systems 246disposed in operative association with production zones of the formation244. More specifically, FIG. 4 illustrates that the present technologiesmay be implemented in a variety of configurations and/or combinations oftechnologies to provide flow control systems 246 according to thevarious implementations described, taught, and suggested herein. Forexample, FIG. 4 illustrates that the flow control systems 246 includetubulars 248, which may be provided in a first tubular configuration 248a and/or in a second tubular configuration 248 b, each of which providepermeable and impermeable sections in different manners as will bedescribed further in connection with subsequent Figures. The tubulars248, while different, have some elements in common. For example, each ofthe tubulars 248 includes an outer member 250 that defines a flowconduit 252 within the tubular. Additionally, each of the outer members250 includes a permeable portion 254 adapted to allow fluid flow throughthe outer member into the flow conduit.

FIG. 4 further illustrates that the tubulars 248 include flow controlapparatus 256, which may be of any of the configurations disclosedherein. Two exemplary flow control apparatus 256 are illustrated in FIG.4. The details of the flow control apparatus' structure andfunctionality will be described in greater detail in connection withlater Figures herein. However, as an introduction, FIG. 4 illustratesthat fluid flow, represented by flow arrows 258, from the formation 244into the tubular 248 follows a tortuous path through at least two flowcontrol mechanisms, here represented as permeable segments associatedwith the outer member 248 and the flow control apparatus 256. In someimplementations of the present technology, it may be preferred to use acommon configuration for each of the flow control systems 246 along thelength of a downhole tubular joint, along the length of a zone isolatedby packers, and/or along the length of an entire operative portion of adownhole string. In other implementations, such as illustrated in FIG.4, the characteristics of the well, the formation, and/or the reservoirmay suggest the use of different flow control system configurations in asingle well. For example, as illustrated schematically in FIG. 2, it ispossible that two production intervals, such as zones 108 c and 108 d,are sufficiently close together that zonal isolation throughconventional packers is not practical. The different zones may includeformations having different characteristics requiring differingcompletions for optimal operation. A configuration such as shown in FIG.4 where different flow control system configurations are disposedadjacent to each other may allow the differing intervals to becompleted, and flows therefrom to be controlled, differently withoutrequiring packers disposed between intervals. Similarly, the use ofmultiple flow control system configurations may be suitable in a varietyof other common field conditions.

FIGS. 5A and 5B illustrate a flow control system 246 in a coaxialconfiguration 260, which configuration is also shown in FIG. 4. Thecoaxial configuration 260 is one example of the various implementationsof flow control systems 246 within the scope of the present disclosure.FIG. 5A illustrates the coaxial configuration 260 in a fully open statewhile FIG. 5B illustrates the coaxial configuration having a flowcontrol chamber 262 blocked by sand 264 or other particulates(hereinafter referred to generically as sand) from the formation 244. Asseen in FIG. 5A, the flow control system 246 in a coaxial configuration260 includes a tubular 248, which includes an outer member 250 thatdefines a flow conduit 252 within the outer member. Tubulars 248 mayinclude nothing more than the outer member 250 or may comprise the outermember 250 together with various other apparatus, such as apparatuscommon in downhole production strings. In implementations where thetubular 248 includes additional apparatus, it should be understood thatthe descriptor “outer” in outer member 250 is relative to the flowconduit 252 defined by the outer member 250 rather than relative to thetubular 248. Tubular 248 and outer member 250 are illustrated in FIG. 5Aas cylindrical members according to convention in the industry; however,other shapes and configurations may be used as well, such as ellipsoidor polygonal. The shape of the tubular 248 may impact the shape of theflow conduit 252 and/or the configuration of the flow control apparatus256 disposed within the flow conduit 252. Additionally or alternatively,the configuration of the outer member 250 may have a greater impact onthe configuration of the flow conduit 252 and/or flow control apparatus.For example, the outer member 250 may be adapted to provide permeableportions 254 and impermeable portions 266 in different locations alongits length and/or periphery, which may affect the flow profile and,therefore, the configuration of the flow control apparatus 256.Accordingly, while FIGS. 5A and 5B illustrate an exemplary coaxialconfiguration 260, other coaxial configurations are within the scope ofthe present disclosure. Similarly, the remaining configurations orimplementations described and illustrated herein are merelyrepresentative and variations and shapes and dimensions of the variousparts are within the scope of the present invention.

Flow control systems 246 of the present disclosure include the outertubular 250, as described above, and a flow control apparatus 256, whichis disposed within the flow conduit 252. The flow control apparatus 256comprises at least one conduit-defining structural member 268 and atleast one chamber-defining structural member 270. The at least oneconduit-defining structural member 268 may be in any configurationadapted to divide the flow conduit 252 into at least two flow controlconduits 272. As illustrated in FIG. 5A, the conduit-defining structuralmember 268 includes a tubular member 274 disposed within the outermember 250 of the tubular 248. In FIG. 5A, the tubular member 274 andthe outer member 250 are concentric, leading to the nomenclature of thecoaxial configuration; however, it should be understood that the tubularmember 274 may be disposed in any position within the flow conduit 252,including offset from the axis of the tubular 248 and/or adjacent to theouter member 250. The at least one conduit-defining structural member268 used to divide the flow conduit 252 into at least two flow controlconduits 272 may comprise a single physical member or may comprisemultiple members, such as tubular members, walls, baffles, etc.

The flow control apparatus 256 also includes at least onechamber-defining structural member 270, as indicated above andrepresentatively illustrated in FIG. 5A. In FIG. 5A, thechamber-defining structural member 270 is provided by a disk 276spanning the annulus between the tubular member 274 and the outer member250. Accordingly, the flow conduit 252 defined by the outer member 250is divided into at least two flow control conduits 272 and at least twoflow control chambers 262. Similar to the conduit-defining structuralmember 268, the chamber-defining structural member 270 may be providedin any suitable configuration, which may be influenced by theconfiguration of the outer member 250 and/or the configuration of theconduit-defining structural members 268. Similarly, the number of andthe spacing between the chamber-defining structural members 270 may varyin implementations within the scope of the present disclosure. In thecoaxial configuration 260 of FIG. 5A, the chamber-defining structuralmembers 270 may be positioned within flow conduit 252 at even intervalsand/or may be positioned in the flow conduit based at least in part onthe measured or expected properties of the formation 244 in the regionoutside of the tubular 248.

A consideration of both FIGS. 5A and 5B will illustrate thefunctionality of the flow control systems 246 described herein. Thefunctionality is first described in general terms and then morespecifically with reference to the specific elements shown in FIGS. 5Aand 5B. As described above, the flow control systems 246 of FIGS. 5A and5B are identical but in two different states of operation. Flow controlsystems 246 of the present invention provide at least two flow controlconduits 272 from a single flow conduit 252. Additionally, at least oneof the flow control conduits 272 is divided into at least one flowcontrol chamber 262. The at least one flow control chamber 262 includesat least one inlet 278 and at least one selective outlet 280. The atleast one inlet 278 allows fluid from outside the tubular 248, such asfrom the well annulus 282 between the formation 244 and the tubular 248,through the outer member 250 and into the flow conduit 252, or, morespecifically, into the flow control chamber 262. The inlet 278 isadapted to provide at least one barrier to flow impairment, such as byscreening sand 264 from the flow. Accordingly, permeable portions 254may provide the inlet 278 that also provides the barrier to flowimpairment (e.g., sand control). The inlet 278 may provide the flowimpairment barrier through any suitable configuration, such as usingconventional sand control mechanisms of wire-wrapped screens, perforatedtubing, pre-packed screens, slotted liners, mesh screens, sintered metalscreens, etc.

Once the produced fluid has entered the flow control chamber 262, thefluid flows toward the outlet 280, which is illustrated in FIG. 5A asbeing offset from the inlet 278. The outlet 280 is also configured as aflow impairment barrier to provide redundancy in the efforts tocounteract the various downhole conditions that can impair fluid flow.For example, and as illustrated in FIG. 5A, the outlet 280 from the flowcontrol chamber 262 may be configured as a permeable segment adapted toretain sand 264 or other particles larger than a predetermined size. Theconfiguration of the outlet may vary depending on the mechanism of flowimpairment being counteracted. Additionally or alternatively, multipleoutlets may be provided from a flow control chamber 262, as will be seenin connection with other Figures herein. The coaxial configuration 260could be adapted to include two outlets by providing perforations, mesh,or other form of permeability in the chamber-defining structural member270. In some implementations of the present invention, the configurationof the outlet and the inlet may be coordinated to provide redundancyagainst the same flow impairment mechanism(s). Additionally oralternatively, the inlet and/or the outlet may be configured to addressadditional and/or different mechanisms.

FIG. 5B illustrates the redundancy of the present flow control systems246. In FIG. 5B, the inlet 278 to the flow control chamber 262 has beenmechanically damaged to allow sand 264 into the flow control chamber262, as illustrated by the hole 284 in the permeable portion 254. Whilesand passing through the sand control devices of conventional productiontubing is a significant flow impairment, FIG. 5B illustrates that theredundant controls of the present inventions provides the outlet 280from the chamber 262 with suitable flow control equipment to restrictthe flow of particulates larger than a predetermined size from the flowexiting the flow control chamber. Accordingly, the sand 264 accumulatesin the chamber until the outlet 280 is effectively blocked by the sandand the flow through the chamber is at least substantially blocked. Inthe implementation of FIGS. 5A and 5B, the flow from the outlet passesinto another flow control conduit that is not divided into chambers andthe fluids travel to the surface. In other implementations, the flowthrough the outlet 280 from one flow control chamber 262 may pass intoanother flow control chamber 262 having one or more outlets adapted toprovide a barrier against a flow impairment mechanism. For example, tocounteract the risks of sand production through the produced fluidsand/or the risks of sand undesirably blocking flow paths. When the fluidflow passes from one flow control chamber to another flow controlchamber, the chambers may be arranged in series to provide stagedcontrol and/or to address multiple flow impairment mechanisms. Forexample, a first flow control chamber may be adapted to control largersand particles while a second flow control chamber may be adapted tocontrol smaller sand particles, etc.

Advantageously, the flow control systems 246 of the present inventionallow production to continue from an interval or zone in which one formof flow impairment has occurred. FIG. 5B illustrates this by showingthat the unblocked flow control chamber 262 continues to produce fluidseven after the outer screen (inlet 278) of the blocked flow controlchamber 262 has failed and allowed sand to enter the flow conduit 252.Moreover, while flow through the lower flow control chamber is blocked,or at least substantially restricted, flow from the formation 244 mayproceed through the well annulus 282 to enter the tubular 248 throughthe inlet 278 associated with the upper, unblocked flow control chamber.The flow path through the well annulus 282 provides yet another form ofredundancy provided by the present flow control systems. Specifically,in the event that the lower flow control chamber is blocked by scaleaccumulation on the inlet thereto or other blockages on the outer memberand inlet, the flow from the formation may continue through the wellannulus 282 to enter adjacent flow control chambers.

The flow control systems 246 of the present disclosure, such as thoseillustrated in FIGS. 5A and 5B, may be adapted to offset the flowcontrol chamber outlet 280 from the flow control chamber inlet 278, suchas in the manner shown in FIGS. 5A and 5B. One of the flow impairmentmechanisms that completion equipment attempts to prevent or address isthe inflow of sand 264 while allowing fluids to flow into the flowconduit. Conventional methods utilize a screen or other permeable mediumto restrict the flow of particulates while allowing fluids to pass.However, the permeability inherently reduces the structural integrity ofthe permeable portions. As solids-laden fluids impact the permeablesegments it is common for these segments to fail and have a hole open inthe permeable portion, such as illustrated by the hole 284 in FIG. 5B.Such holes defeat the sand-control objectives of the permeable segmentsand sand is allowed to flow into the production equipment. The risk ofmechanical failure of the permeable segments increases in cased and/orfractured wells where produced fluids enter the well annulus 282 atdiscrete, focused sources.

The offset relationship between the flow control chamber inlet 278 andthe flow control chamber outlet 280, which may be incorporated into oneor more of the implementations herein, may provide an additional barrieragainst flow impairment due to mechanical failure of the completionsequipment. Referring to FIG. 5 as an exemplary implementation, flowentering the flow control chamber 262 passes through the inlet 278 in afirst direction; flows through the flow control chamber in a seconddirection; and exits through the outlet 280 by flowing in yet a thirddirection. The flow control apparatus 256 includes impermeable portions266 adapted to provide a strengthened structural member in the vicinityof the inlet 278 to the flow control chamber 262. Accordingly, while theinlet 278 may cause fluids to be more concentrated in a particular flowdirection, the flow control apparatus 256 is adapted to redirect thatenergy into a second flow direction, dissipating the energy carried bythe entrained particles and encouraging the particles to drop out of theflow. This initial turn may be sufficient to sufficiently reduce themechanical failure risk imposed by entrained particles impactingpermeable segments. However, some implementations, such as illustratedin FIGS. 5A and 5B impose yet another flow direction change beforepassing through the outlet 280. The tortuous path followed by theparticles attempting to flow through the production tubular 248 with theproduced fluids reduces the energy of the particles and facilitates thetask of the permeable portion providing the outlet 280 from the flowcontrol chamber. The tortuous path may be induced in a variety ofmanners, some of which are illustrated and described in the presentdisclosure, and all of which are within the scope of the presentinvention.

Turning now to FIGS. 6A-6F, further implementations and features of flowcontrol systems within the scope of the present invention will bedescribed. The illustrations of FIGS. 6A-6F are highly schematic andintended to represent combinations of permeable surfaces and impermeablesurfaces that may be used to form flow control conduits and flow controlchambers within the scope of the present invention. While the permeableportions are represented by dashed lines are visually similar toconventional wire-wrapped screens, which may be used in the presentinvention, the permeable portions illustrated here are more broadly andschematically representing any of the variety of manners through whichfluids may be allowed to pass through the outer member into the flowcontrol chamber. For the sake of clarity in describing the variousschematics of FIGS. 6A-6F, reference numbers will be used in connectionwith FIGS. 6A-6F that are different from those reference numbers used torefer to similar or identical elements or features in FIGS. 4 and 5.Similarly, the remaining Figures herein may use different referencenumerals to aid in the clarity of the description of those Figures. Theterms and nomenclature used to refer to common elements and features areconsistent across the Figures and may be referred to in considering thesimilarities between the various implementations disclosed herein.

Beginning with FIGS. 6A-6C, three different operational configurationsof a flow control system 300 are schematically illustrated. The flowcontrol system 300 of FIGS. 6A-6C is illustrated as including an outermember 302 forming a well annulus 304 between the formation 306 and theouter member 302. However, for purposes of discussion and simplicity inillustration, only half of a side cross-sectional view is illustrated.As discussed previously, the outer member 302 also defines a flowconduit 308 within the outer member 302. Additionally, the flow controlsystem 300 further includes flow control apparatus 310, which includesconduit-defining structural members 312 adapted to divide the flowconduit 308 into at least two flow control conduits 314 andchamber-defining structural members 316 adapted to divide at least oneof the flow control conduits 314 into at least two flow control chambers318. As one exemplary implementation that may be represented by theschematic of FIGS. 6A-6C, the coaxial configuration of FIGS. 5A and 5Bwould have a side cross-sectional view comparable to that of FIGS.6A-6C.

FIGS. 6A-6C illustrate a flow control system 300 having outlets 320 fromthe flow control chambers 318 that are adapted to be selectively opened.As seen in FIG. 6A comparing FIGS. 6A-6C, the outlets 320 are bothclosed in FIG. 6A, preventing fluid flow through the flow controlchambers 318. Accordingly, FIG. 6A illustrates a first operatingconfiguration for flow control systems within the scope of the presentdisclosure in which the flow control system effectively acts as a blankpipe section. As illustrated by flow arrow 322, fluid in the wellannulus 304 effectively stays in the well annulus as it passes the flowcontrol system 300. Similarly, as illustrated by flow arrow 324, fluidwithin the flow control conduit 314 a (which may have entered the flowcontrol conduit from a portion of the well closer to the toe) stayswithin the flow control conduit 314 a.

FIG. 6B illustrates the flow patterns when one of the outlets 320 isopened. As illustrated in FIGS. 6A-6C, the chamber-defining structuralmembers 316 are more than a simple disk as illustrated in FIG. 5 andinclude both permeable segments and impermeable segments, which togetherare adapted to provide the selectively opening outlet 320 introducedabove. The outlet 320 may be selectively opened through any of a varietyof techniques, including chemical means (dissolution or othermodifications of portions of the impermeable segment incorporatingstimulus-responsive materials), mechanical means (sliding sleeves orother elements that are moved via hydraulic, electric, or other signalsand controls), or other means (such as perforations or other availabledownhole tools). It should be understood that the physicalimplementation of a selectively opening outlet 320 may be asschematically illustrated here or in any other suitable method, such asa wire-wrapped screen having spaces filled by a material that can bedissolved or reduced in size to allow flow between the wrapped wires.

As illustrated, once the outlet 320 is opened fluid from the wellannulus 304 passes into the flow control chamber 318 a, through theoutlet 320, and into the flow control conduit 314 a for communicationfurther up the well toward the surface. FIG. 6B illustrates that aselectively opening outlet 320 allows operator control over which flowcontrol chambers 318 are operative at any given time, which may be usedto control production rates or to control the type of completion applied(such as restricting smaller or larger particles). In someimplementations, the selectively opening outlets 320 allow an operatorto stage the production from a particular production zone. For example,as illustrated in FIG. 6B, fluids are produced through flow controlchamber 318 a and associated outlet while flow through flow controlchamber 318 b is blocked by the closed outlet. Subsequently, and asillustrated in FIG. 6C, the flow through flow control chamber 318 a isblocked by the accumulation of sand 326 by the outlet 320 a, which isadapted to retain particles larger than a predetermined size. When theproduction through flow control chamber 318 a is substantially blockedby the accumulated sand 326, flow control chamber 318 b and outlet 320 bmay be opened to allow continued production from the production zonewhile continuing to protect the production operation from flowimpairment, such as sand inflow in this example. By staging theproduction in a production zone, the flow rate from that zone can bemaintained for a much longer period of time without requiring a fullworkover. In some implementations, the outlet 320 b may be adapted toapply a different degree of sand control compared to the outlet 320 a.For example, the sand control features of outlet 320 b may be allowlarger particles to pass through to prevent accumulation of sand 326 atthe outlet blocking flow through outlet 320 b, which may allow theproduction to continue with a controlled amount of sands or finesproduction. Additionally or alternatively, the spacing between theinlets 328 to the respective flow control chambers may be sufficientlyfar to effectively limit or prevent sand from one formation zone (e.g.,the zone adjacent to flow control chamber 318 a) passing to the inlet ofan adjacent flow control chamber through the well annulus 304.Accordingly, the configuration of the outlets 320 a and 320 b inadjacent flow control chambers may be different to retain the sand thatis anticipated from the different formation zones. The configuration ofoutlets to retain particles larger than a predetermined size may be doneon a chamber-by-chamber basis or may be done for the entire well. In anyevent, the predetermined size that is retained by a given outlet may beinfluenced by the formation, by the well, by the completion, by themanner in which the well is to be used, by the manner in which the flowcontrol system is designed, and a variety of other factors.

FIG. 6C further illustrates that one or more of the chambers may beprovided with a bare outlet 332 without sand control features, such asthe outlet 332 illustrated in flow control chamber 318 a. Such an outletmay be provided in a variety of circumstances where the economics orcircumstances of the well no longer necessitate or suggest thedesirability of the present, redundant flow control systems. Forexample, the redundant controls of the present flow control systems maybe implemented during a period of time to maximize the life of thecompletion and productivity of the well interval while minimizing thesand production. However, there may be a time in the life of the wellthat some amount of sand production is acceptable as compared to acomplete workover. For example, if all of the flow control systems in acompletion have become blocked and the next step is to withdraw theproduction tubing for a workover, it may be preferred to open a bareoutlet 332 in one or more of the flow control chambers to continue theproduction for a time with anticipated sand or fines production.

While FIGS. 6A-6C illustrate flow profiles in a flow control system 300having staged utilization of the different flow control chambers 318,the flow profile through an inlet 328, through the flow control chamber318, and through an outlet 320 is representative of the flow profiles ofthe implementations described in the present invention. Similarly, theschematic representation of the locations and orientations of the flowcontrol chambers, the flow control conduits, the outer member, theconduit-defining structural members, the chamber-defining structuralmembers, the inlets, the outlets, etc. are all representative only andmay be embodied or implemented in any suitable configuration, includingthose described in greater detail herein. As described above, any one ormore of these components may be referred to differently in an injectioncontext rather than the production context described above. For example,outlet 320 may be considered an inlet to the flow control chamber andinlet 328 may be considered an outlet from the flow control chamber.

FIGS. 6D-6F provide further schematic illustrations of flow controlsystems 300 within the scope of the present invention. The flow controlsystem 300 of FIG. 6D-6F includes many of the same features describedabove but arranged in a different implementation. Flow control system300 includes an outer member 302 adapted to provide an inlet 328therethrough and to define a flow conduit 308 therewithin. The flowcontrol system 300 is disposed in a well such that the outer member 302defines a well annulus 304 between the formation 306 and the outermember. Similar to the implementation described above, the flow controlsystem 300 of FIGS. 6D-6F includes a flow control apparatus 310 adaptedto be disposed within the outer member 302. The flow control apparatus310 includes at least one conduit-defining structural member 312defining at least two flow control conduits 314 within the flow conduit308. Additionally, the flow control apparatus 310 includes at least onechamber-defining structural member 316 configured to divide at least oneflow control conduit 314 into at least two flow control chambers 318.Additionally, the flow control apparatus 310 is configured to provide atleast one outlet 320 from the flow control chamber 318.

As can be seen in FIGS. 6D-6F, the flow control systems 300 within thescope of the present inventions may include two or more outlets 320 perflow control chamber 318. Following the progression of operations fromFIG. 6D to FIG. 6F, it can be seen that a first outlet 320 is opened inFIG. 6D to allow flow through the flow control chamber 318. The outlet320 is provided with a permeable portion 330 or other features tocounteract at least one flow impairment mechanism. For example, theoutlet 320 may be provided with a screen or mesh to retain particleslarger than a predetermined size. Additionally or alternatively, theoutlet 320 may be adapted to counteract mechanical failure of the screenor mesh by being fluidically offset from the inlet 328, as discussedabove. As illustrated in FIG. 6D, one outlet 320 is open while the otheris closed. In some implementations, two or more outlets may be open atthe same time depending on the flow parameters desired for theparticular well, zone, and/or chamber of the production equipment.

As illustrated in FIG. 6E, the second outlet 320 is opened once thefirst outlet 320 is effectively and/or substantially closed by theaccumulation of sand or other particles. 326. The selective opening ofthe outlets 320 allows the operator to control the flow through theindividual flow control chambers. In some implementations, the selectiveopening of the outlets is controlled from the surface through anysuitable means. The control from the surface for opening an outlet isacceptable because delays in opening an outlet do not introduceincreased risks of flow impairment or damage to the productionequipment. Additionally or alternatively, control of the variousselectively opening outlets 320 may be effected passively, or withoutdirect operator or surface intervention. For example, the second openedoutlet 320 in FIG. 6E may be configured to open when pressure from theflow control chamber 318 exceeds a predetermined set point selected toindicate that the first outlet is sufficiently blocked by particles.Additionally or alternatively, the positioning of the second outletwithin the chamber may be sufficient to render it effectively closeduntil the first outlet becomes sufficiently blocked. For example, inFIG. 6E, the flow in the well annulus 304 is illustrated as moving fromright to left. The flow will tend to enter the inlet 328 and continue inthe right to left manner towards the first opening 320 (illustrated asopen in FIG. 6D and closed in FIG. 6E). Natural flow forces will notdirect substantial flows toward the second outlet 320 until there issufficient back pressure against the first outlet.

As described above, in some implementations the staged or selectivelyopening outlets may be implemented for the purpose of maintainingproduction rates over an extended period of time from the same segmentof the formation. Additionally or alternatively, staged or selectivelyopening outlets may be implemented for the purpose of counteractingdifferent flow impairment mechanisms and/or different degrees of risksof flow impairment. As one example of such an implementation, a firstoutlet may be configured to retain a first predetermined size ofparticles while the second outlet may be configured to retain a second,larger predetermined size of particles. Accordingly, the well, or regionof the well, may be operated for a first time during which all particleslarger than the smaller, first predetermined size are retained andaccumulated against the outlet. When the second outlet is opened, flowmay resume or continue from that chamber and will allow particlessmaller than the second predetermined size to pass through the outlet.Such an implementation may be suitable when differing degrees of flowquality and/or risks are tolerated at different stages in the life of awell. FIG. 6F illustrates a still further configuration of the flowcontrol system 300 wherein both of the outlets 320 including permeableportions 330 are blocked. In such a condition flow through the chamber318 would be blocked. However, in some implementations, it may beacceptable to open a bare outlet 332 that is not adapted to retainparticles or otherwise prevent or counteract a flow impairmentmechanism. Flow may then resume through the flow control chamber 318.Such an implementation may be used when the sand production risk hasbeen minimized or when the risks of sand production are acceptable inlight of the other conditions associated with the continued operationsof the well, such as the workover costs, etc.

FIGS. 7A-7C schematically illustrate still additional implementations offlow control systems within the scope of the present invention. Asdescribed above, FIGS. 5A and 5B illustrated a coaxial configuration ofthe flow control systems and FIGS. 6A-6F illustrated schematically flowdiagrams characteristic of various configurations and implementations tobe described herein. FIG. 7A illustrates an end view of a trifurcatedflow control system 350. As with the other implementations described andclaimed herein, the trifurcated flow control system 350 includes anouter member 302 defining an internal flow conduit 308. As illustratedin FIG. 7A, the flow conduit 308 is trifurcated by a flow controlapparatus 310 including conduit-defining structural members 312 in theform of three partitions 352. The partitions 352 divide the flow conduit308 into three flow control conduits 314, any one or more of which maybe divided further by chamber-defining structural members (not shown).The trifurcated configuration 350 of FIG. 7A is representative of thevarious manners in which conduit-defining structural members may bedisposed to divide the flow conduit 308 into two or more flow controlconduits 314. The partitions 352 may be configured as solid panelsand/or may be configured to provide outlets (not shown in FIG. 7A), suchas those described elsewhere herein, to allow flow between adjacent flowcontrol conduits 314 and/or chambers. Additional, more detailed examplesof trifurcated and/or multi-furcated flow control systems 350 areprovided below.

FIG. 7B provides a schematic end view of another implementation of afurcated flow control system. FIG. 7B schematically illustrates a flowcontrol system 300 in a coaxial-furcated configuration 360. Thecoaxial-furcated configuration 360 is yet another example of the variousmanners in which a flow control apparatus 310 may be implemented withinan outer member 302 of a flow control system 300. As illustrated, thecoaxial-furcated configuration 360 includes a plurality ofconduit-defining structural members 312, including an inner tubular 362and three partitions 364 extending between the outer member 302 and theinner tubular 362, partitioning or dividing the annulus therebetweeninto multiple flow control conduits 314. Additionally, the inner tubular362 provides yet another flow control conduit 314. Any one or more ofthese flow control conduits 314 may be divided into flow controlchambers (not shown) through the use of chamber-defining structuralmembers (not shown), which may be adapted to conform or substantiallyconform to the dimensions of the flow control conduits 314. In exemplaryimplementations, each of the exterior flow control conduits 314 a may beformed into flow control chambers while the inner flow control conduit314 b may be left open for unimpeded flow of fluids through the tubingstring. Similar to the schematic illustration of FIG. 7A, theconduit-defining structural members 312 of FIG. 7B, including the innertubular 362 and the partitions 364, may be configured as solid panelsand/or may be configured to provide outlets (not shown in FIG. 7B), suchas those outlets described elsewhere herein, to allow flow betweenadjacent flow control conduits and/or chambers.

FIGS. 8A-8D provide yet another exemplary implementation of acoaxial-furcated configuration 360. The implementation illustrated inFIG. 8A shows that the flow control apparatus 310 may include multipleconduit-defining structural members 312 disposed and configured in anysuitable manner to create at least two flow control conduits 314 fromthe flow conduit 308 defined by the outer member 302. As illustrated inFIG. 8A, the coaxial-furcated configuration 360 effectively provides aplurality of concentric flow control conduits 314 a, 314 b, 314 cthrough the use of multiple inner tubulars 362. The outer memberincludes at least one inlet 328 to the flow conduit 308, andparticularly to the flow control conduit 314 a.

With continuing reference to FIG. 8A, once the fluid has entered theflow conduit 308, it is able to flow within the flow control chamber 318a defined by the conduit-defining structural members 312, thechamber-defining structural members 316 and the outer member 302. Fluidin the outer flow control conduit 314 a or outer flow control chamber318 a may then exit the flow control chamber through outlets 320provided in the conduit-defining structural member 312, which may be anysuitable form of outlet providing fluid communication between the outerflow control conduit 314 a and the intermediate flow control conduit 314b. The configuration of the outlet 320 may vary depending on the flowimpairment mechanism for which the flow control system 300 is adapted.Exemplary outlets may provide a permeable portion, such as describedabove, adapted to retain particulate material larger than apredetermined size.

As illustrated by the configuration of the outer member 302, the inlet328 providing fluid communication between the well annulus 304 and theflow conduit 308 may be adapted to counteract flow impairment asdescribed herein. For example, the inlet 328 may be a wire-wrappedscreen, a mesh, or configuration adapted for sand control. Exemplaryconfigurations of the outer member 302 may include an inlet 328 providedby a wire-wrapped screen having gaps between adjacent wires that issufficient to retain formation sand produced into the wellbore largerthan a predetermined size. Other portions of the outer member 302 may beprovided in any suitable manner such as blank pipe, impermeable materialwrapped on the outside of a permeable media, or a wire-wrapped screenwithout a gap between adjacent wires. Manufacturing of a wire-wrappedscreen is well known in the art and involves wrapping the wire at apreset pitch level to achieve a certain gap between two adjacent wires.Some implementations of suitable outer members may be manufactured byvarying the pitch used to manufacture conventional wire-wrapped screens.For example, one portion of an outer member may be prepared by wrappinga wire-wrapped screen at a desired pitch that would retain formationsand larger than a predetermined size and wrapping the next portion atnear zero or zero pitch (no gap) to create an essentially impermeablemedia section. Other portions of the outer member 302 could be wrappedat varying pitches to create varying levels of permeable sections orimpermeable sections.

The inner tubulars 362 may be provided in a manner similar to the mannerdescribed for the outer member 302 using wire-wrapped screen techniques.Using the variety of wire configurations available and the variety ofpitches, the outlets 320 provided by the permeable portions may beprovided in a multitude of configurations suitable for retainingparticles of any predetermined size. Additionally or alternatively, thepermeable portions on the flow control apparatus 310 (as compared to thepermeable inlet on the outer member 302) may be provided in othersuitable manners to provide the desired functionality, such as theselectively opening outlets 320 described in connection with FIG. 6. Inimplementations where the outlet 320 from the flow control chamber 318is fluidically offset from the inlet 328 to the flow control chamber,greater flexibility in the configuration of the outlet may be available.As discussed above, the fluidically offset inlet 328 and outlets 320provide an impermeable, and therefore stronger, conduit-definingstructural member 312 in the region in the fluidic path from the wellannulus 304 through the inlet 328 to resist mechanical damage to thechamber-defining structural member 312 due to the force of the incomingfluid and/or particles.

In the exemplary configuration shown in FIGS. 8A-8D, the flow conduit308 is divided into two annular flow control conduits 314 by the innertubulars 362 which are further divided into longitudinal flow controlconduits by the partitions 364 extending within the annular flowconduits (as seen in FIGS. 8B-8D). Flow entering a flow control conduit314 through an inlet 328 encounters the impermeable member of theconduit-defining structural member 312, as seen by flow arrow 366 inFIG. 8A. The flow is then diverted, together with the dissipation ofenergy carried by the fluids and particles in the flow, longitudinallywithin the longitudinal flow control conduits 314 created and defined bythe flow control apparatus and conduit-defining structural member 312,as seen by flow arrows 368. The flow is then isolated longitudinally bythe chamber-defining structural members 316. Outlets 320, which may beselectively opening outlets, provide fluid communication between theouter longitudinal flow control conduit 314 a and the intermediatelongitudinal flow control conduit 314 b. As discussed above and similarto the inlet 328, the outlets 320 may be provided by a permeable portionor in another suitable configuration to retain particles larger than apredetermined size. The flow within the intermediate flow controlconduit 314 b may then pass through outlet 320 into the inner flowcontrol conduit 314 c, as seen by flow arrows 370, or may flowlongitudinally along the intermediate flow control conduit 314 b, asseen by flow arrows 372. For example, in the event that one of theoutlets 320 from the intermediate flow control conduit 314 b becomesblocked by particle accumulation, the fluids may flow longitudinally tothe other outlet 320 to maintain production from the respective sectionof the production tube. Additionally or alternatively, the outlets fromthe intermediate flow control conduit 314 b may be fluidically offset(not shown) from the outlets from the outer flow control conduit 314 c.Once the fluids pass through the outlet 320 from the intermediate flowcontrol conduit 314 b to the inner flow control conduit 314 c, thefluids are in fluid communication with the surface and are part of theproduction flow represented by flow arrows 374.

In some implementations, the outer flow control conduit 314 a andassociated outlet may be adapted to provide an initial filter to retainlarger particles while allowing finer particles to pass through and theintermediate flow control conduit 314 b and associated outlet may beadapted to provide a final filter to remove smaller particles.Additionally or alternatively, the outer and intermediate flow controlconduits and associated outlets may be substantially similar and provideredundancy at the same level of filtration rather than differing degreesof filtration. In any event, should the inlet 328 fail and allowparticles to enter the flow conduit 308, the outer flow control conduit314 a and associated outlet provide a first barrier to the infiltrationof sand into the production stream 374. Additionally, in the event thatthe outlet 320 from the outer flow control conduit 314 a is designed toallow some particles through or in the event of mechanical failure ofthe outlet, the intermediate flow control conduit 314 b and associatedoutlet provide a second barrier to the infiltration of sand into theproduction stream. Coupled with the energy dissipation of thefluidically offset inlets and outlets, the flow control systems 300 ofthe present disclosure provide enhanced abilities to prevent flowimpairment due to the multiple redundant flow paths formed within theouter member 302 and the flow conduit 308. In the event that each of theoutlets from a given flow control chamber 318 is blocked orsubstantially blocked due to particle accumulation (or due to thepossible configuration as selectively opening), production fluids fromthe adjacent formation may enter the well annulus 304 and proceed to anadjacent segment of the production tubing string that is not yetblocked. Accordingly, the redundant flow paths and redundant systems toallow production operations to continue while preventing sandinfiltration and overcoming other forms of flow impairment.

FIGS. 8B, 8C, and 8D are cross-sectional views of FIG. 8A at thedesignated locations of FIG. 8A wherein like elements from FIG. 8A aregiven the same reference numbers. These figures illustrate the changesfrom permeable walls (dashed lines) to impermeable walls (solid lines)based on the location in the wellbore. Additionally, while notillustrated in FIGS. 8A-8D, any one of the conduit-defining structuralmembers 312, such as the partitions 364, may be provided with permeableportions to provide an outlet from one longitudinal flow control conduitto an adjacent flow control conduit. Fluid communication betweenlongitudinal flow control conduits illustrated in FIGS. 8A-8D mayprovide still further redundancies in the flow paths to permit fluidflow while countering the flow impairment mechanisms. The configurationand disposition of the outlets formed in the partitions 364 mayincorporate the fluidic offset principles described above, such as bybeing disposed longitudinally offset from the inlet 328. Additionally oralternatively, outlets on partitions may be disposed in longitudinalalignment with the inlet 328 while still providing the fluidic offsetadvantages described above. As described above, the fluidic offsetbetween inlets and outlets may be implemented to dissipate the energy inincoming flows against a solid, and therefore more resistant,conduit-defining structural member rather than an outlet. The offsetcauses the incoming flow to change directions upon entering the flowcontrol conduit (e.g., from a radially directed flow through the inletto a longitudinally directed flow in FIG. 8A). The longitudinally offsetoutlets illustrated in FIG. 8A force another flow direction change asthe flow passes through the outlet (e.g., from longitudinal flow in theconduit to radial flow through the outlet). In implementations providingone or more outlets in the partitions 364, similar flow directionalchanges are created. For example, radial flow through the inlet ischanged to circumferential flow due to the relationship between thesolid inner tubular and the outlet in the partition.

FIGS. 9A-9D provide an example of the flow control system 300 furtheradapted for use in operations requiring flow in the reverse or injectiondirection, such as treatment operations and/or gravel packingoperations. FIGS. 9A-9D are analogous in many respects to thecoaxial-furcated configuration 360 of FIGS. 8A-8D and similar referencenumerals refer to similar elements without their express recitation herein connection with FIGS. 9A-9D. As illustrated in FIGS. 9A-9D, one ormore of the flow control conduits 314 may be configured as an injectionconduit 376. The exemplary configuration illustrated includes a shunttube 378 disposed within the injection conduit 376 and nozzles 380extending from the shunt tube through the outer member 302. When a shunttube 378 is used, the injection conduit 376 may have sufficient spaceremaining to allow the flow control conduit to be used for productionpurposes as well. Alternatively, the flow control conduit in which theshunt tube is disposed may be adapted for exclusive use as a conduit forthe shunt tube. Additionally or alternatively, one or more of the flowcontrol conduits 314 may be adapted for injection operations without theuse of shunt tubes 378. For example, the use of solid, impermeableconduit-defining structural members and appropriate inlets and outletsmay enable one flow control conduit to be used for injection operationswhile an adjacent flow control conduit is adapted for productionoperations. The incorporation of shunt tubes 378 and/or injectionconduits 376 may allow the present flow control systems to be used ingravel packing operations, such as disclosed in U.S. Pat. Nos.4,945,991, 5,082,052, and 5,113,935.

FIGS. 10A and 10B provide a cut-away side view and a cross-sectionalview, respectively, of yet another implementation of flow controlsystems 400 within the scope of the present invention. While theeccentric configuration 402 is illustrated and described separately fromthe implementations and configurations described above, the features andaspects of this implementation, as with the other implementations andconfigurations described herein, are interchangeable betweenconfigurations. For example, configurations of the outlets and inletsdescribed above in connection with the coaxial implementation, thefurcated implementation, and/or the coaxial-furcated implementation maybe utilized in the eccentric configuration 402 without specificrepetition of such features or configurations in connection with theeccentric configuration. Similar to the implementations described above,the eccentric configuration 402 incorporates flow path redundancy andredundant flow impairment countermeasures to enhance the longevity andfunctionality of the downhole equipment. The eccentric configuration 402of FIGS. 10A and 10B is illustrated in the context of countering thesand infiltration flow impairment mechanism, but is also effective incountering the effects of scale build-up on inlets to the productionequipment. Additionally, to the extent that increases in sand productionare often associated with corresponding increases in water production,the present flow control systems may be effective in countering thewater production flow impairment mechanism.

As illustrated in FIGS. 10A and 10B, the eccentric configuration 402includes a tubular 404 having an outer member 406 that defines a flowconduit 408. Within the flow conduit 408 is disposed a flow controlapparatus 410 having conduit-defining structural members 412 adapted todivide the flow conduit 408 into at least two flow control conduits 414and having chamber-defining structural members 416 adapted to divide atleast one of the flow control conduits 414 into at least two flowcontrol chambers 418. The outer member 406 is also provided with aninlet 420 represented by the perforations 422. The perforations 422 orother inlet means providing fluid communication between the well annulus424 and the flow control conduit 414 may be adapted to retain particleslarger than a predetermined size or may be otherwise adapted to countera flow impairment mechanism. The flow control apparatus 410 alsoincludes an outlet 426 adapted to provide fluid communication betweenthe outer flow control conduit 414 a and the inner flow control conduit414 b. The outlet 426 is represented or illustrated by perforations 428and may be provided in any suitable manner to counter one or more flowimpairment mechanisms, such as described elsewhere herein. Asillustrated in FIGS. 10A and 10B the outer member 406 and components ofthe flow control apparatus 410 may be provided by conventional pipesprovided with perforations to provide the appropriate inlets andoutlets. While the perforations themselves may be adapted to retainparticles larger than a predetermined size (or provide some othercountermeasure to flow impairment), the outer member 406 and/or the flowcontrol apparatus 410 may include sandscreens 434, which may extendalong the entire length of the member as illustrated or only over theperforated lengths.

With reference to FIG. 10B, it can be seen that the eccentricconfiguration 402 is provided with two types of conduit-definingstructural members 412, including an inner tubular 430 disposedeccentrically within the outer member 406 and dividing the flow conduit408 into an inner flow control conduit 414 b and an outer flow controlconduit, which is further divided by partition 432 into a first outerflow control conduit 414 a and a second outer flow control conduit 414c. The degree of eccentricity and the relative sizes of the various flowcontrol conduits are representative only and may be varied depending onthe implementation.

FIGS. 10A and 10B illustrate the manners in which the redundant flowpaths can extend the life of a completion despite efforts of theformation to impair the production operations, such as through sandproduction. Considering the implementation of FIG. 10A, flow controlchamber 418 a is illustrated as having a failed sandscreen at the inlet420 thereto allowing sand 436 to enter the flow control chamber 418 a.As sand accumulates in flow control chamber 418 a, the resistance toflow increases and less fluid passes through the outlet 426 from theflow control chamber 418 a. Accordingly, less fluid enters the flowcontrol chamber 418 a, as illustrated by the dashed flow lines 438. Thechamber-defining structural member 416 and the outlet 426 blocked orsubstantially blocked by the infiltrated sand creates an effectiveisolated stage while allowing continued production of fluids fromadjacent the isolated stage through the well annulus 424 and the flowcontrol chamber 418 b, following the detoured flow path represented bydetour flow line 440.

The illustration of FIG. 10A illustrates two advantageous scenarios thatmay occur during operation of a well provided with a flow control systemof the present invention. As described above, the infiltrated flowcontrol chamber 418 a becomes packed with sand 436. While the outlet 426may become completely blocked by the accumulated sand, it is alsopossible that the outlet 426 functions as a conventional sandscreen andthe infiltrated sand 436 functions as a natural sand pack within theisolated flow control chamber 418 a. The possibility of a natural sandpack forming from the infiltrated sand may depend on the nature of theformation in which the flow control system 400 is disposed.Additionally, however, the configuration of the flow control chamber 418a and the outlet 426 therefrom may promote or discourage the formationof a natural sand pack from the infiltrated sand. In someimplementations, the completion engineers and/or equipment manufacturersmay adapt the flow control apparatus 410 to encourage the formation of anatural sand pack in the infiltrated flow control chambers. The naturalsand pack in flow control chamber 418 a may allow continue hydrocarbonproduction through the flow control chamber while retaining sand fromentering the inner flow control conduit 414 b and further protecting theoutlet 420 from mechanical damage.

Additionally or alternatively, the redundant, detour flow path 440provided by the flow control system 400 dissipates the energy of sandentrained in the flow entering the well annulus adjacent the infiltratedflow control chamber 418 a. As illustrated in FIG. 10A, the sandentrained fluid enters the well annulus 424 and is forced to travellongitudinally through the annulus before encountering another inlet 420through the outer member 406. As described above, the change indirection forced by the fluidic offsets dissipates energy that may bestored in entrained sand. FIG. 10A illustrates that the fluidic offsetmay be established in the well annulus as well as in the flow controlconduits within the flow conduits of the present flow control systems.

FIG. 10B illustrates yet another manner in which the eccentricconfiguration 402 provides redundant flow paths and redundant protectionfrom flow impairment. As illustrated in FIG. 10B, infiltrated sand 436may enter only one of the outer flow control conduits, such as the firstouter flow control conduit 414 a. In such circumstances, the producedfluids may flow circumferentially around the outer member 406 to enterthe second outer flow control conduit 414 c, which not yet infiltratedin the illustration of FIG. 10B. Similar to the circumstancesillustrated in FIG. 10A, the infiltrated flow control chamber 418 a mayprovide a natural sand pack in some implementations allowing producedfluids to continue through the infiltrated flow control chamber 418 a,albeit at lower rates. Additionally or alternatively, the circumstancesof FIG. 10B illustrate that the detoured flow paths 440 may runcircumferentially as well as or as an alternative to the longitudinalflow illustrated in FIG. 10A.

As described above in connection with the other configurations of thepresent invention, the various structural members of the flow controlapparatus 410 may be adapted to provide permeable segments asappropriate to create the redundant flow paths and the redundantparticle retention systems described herein. For example, partition 432and/or chamber-defining structural members 416 may be provided withperforations, mesh, wire-wrap or other means to provide fluidcommunication between flow control conduits and/or flow controlchambers.

Turning now to FIGS. 11A and 11B, an enlarged view of the other flowcontrol system from FIG. 4 is illustrated. Similar to the discussionrelated to FIGS. 5A and 5B, the operation of this flow control systemconfiguration will now be described in greater detail. FIGS. 11A and 11Billustrate a partial cutaway view of a flow control system 500 in astepped configuration 502. As with prior illustrations, the flow controlsystem 500 is disposed within a well 504 in a formation 506, forming awell annulus 508 between the flow control system and the formation.While the flow control system 500, as well as other implementationsdescribed herein, is illustrated representatively as being in an openhole well, the systems and methods of the present invention are usefulin cased hole wells as well.

The stepped configuration 502 of the flow control system 500 includes atubular 510 that includes an outer member 512. As illustrated, thetubular 510 includes a perforated base pipe and a wire-wrapped screen.In this implementation, the perforated base pipe provides the outermember 512 that defines a flow conduit 514 and that provides an inlet516 to the flow conduit allowing fluid communication between the flowconduit and the well annulus 508. The perforations 518 are one exampleof an inlet to the flow conduit 514. Similarly, the perforated basepipeis only one example of the variety of manners of providing an outermember having an inlet and defining a flow conduit. Other suitable meansare known to those of skill in the art and are included within the scopeof the present invention. It should be noted that the tubular associatedwith flow control conduit 526 c is not provided with perforations orother means for providing an inlet to the flow conduit. Accordingly, theonly way for fluid to enter the flow control conduit 526 c (describedfurther below) is by passing through a flow control chamber. Flowcontrol conduits that only are in fluid communication with the formationor well annulus through a flow control chamber may be considered aproduction flow control conduit, which may be in communication with thesurface.

With continuing reference to FIGS. 11A and 11B, the steppedconfiguration 502 of the flow control system 500 includes a flow controlapparatus 520 disposed within the flow conduit 514. Similar to thoseimplementations described elsewhere herein, the flow control apparatus520 includes conduit-defining structural members 522 andchamber-defining structural members 524. The conduit-defining structuralmembers 522 are adapted to divide the flow conduit 514 into at least twoflow control conduits 526. In the illustrated implementation of astepped configuration, the conduit-defining structural members 522 areprovided by a plurality of partitions 528 arranged to trifurcate theflow conduit. Additionally or alternatively, additional conduit-definingstructural members may be provided to further divide the flow conduit514. The partitions 528 of the conduit-defining structural members 522include both permeable sections 530 and impermeable sections 532. Thepermeable sections 530 are adapted to allow fluid communication betweenadjacent flow control conduits 526 while retaining particles larger thana predetermined size. Accordingly, the permeable sections 530 are onemanner of providing an outlet 534 from the flow control chambers 536defined by the chamber-defining structural members.

The impermeable sections 532 are adapted to prevent flow fluidtherethrough. As illustrated in FIG. 11A, the impermeable sections 532are disposed in operative association with the perforations 518. Theimpermeable sections of the flow control apparatus may be arranged oradapted to be in direct fluid communication with the inlet 516 so as toabsorb and/or deflect the energy carried by the entering fluids andparticles. Additionally or alternatively, the impermeable sections 532may be disposed so as to cause the outlets 534 from the flow controlchambers 536 to be fluidically offset from the inlets 516. While theillustrated implementation provides impermeable sections 532 on only onepartition forming flow control conduit 526 b, other implementations mayprovide alternative configurations including impermeable sections onboth partitions and/or in different relationships.

The stepped configuration 502 of FIGS. 11A and 11B provide three flowcontrol conduits 526 a-526 c with two flow control conduits divided intoa plurality of flow control chambers 536. As illustrated, the flowcontrol chambers 536 in each flow control conduit are stackedlongitudinally in the flow conduit while the flow control chambers inadjacent flow control conduits 526 are offset from each other. Moreover,as illustrated in FIGS. 11A and 11B, the partition 528 a includespermeable sections to allow fluid flow between flow control chambers inadjacent flow control conduits. Accordingly, in this implementation, thepartition provides at least one outlet from the flow control chambers536. Additionally, as illustrated in FIGS. 11A and 11B, the partitions528 b and 528 c include permeable sections 530 adapted to allow flowfrom the flow control chambers 536 into the flow control conduit 526 c,which is not divided into flow control chambers.

The stepped configuration 502 operates or functions in a manner similarto the configurations described elsewhere herein. For example, the flowcontrol apparatus 520 divides the flow conduit into a plurality of flowcontrol conduits and flow control chambers. The flow control conduitsand flow control chambers provide redundant flow paths through thetubular and provide redundant countermeasures to resist flow impairment,particularly flow impairment due to sand production and/or particleaccumulation or scaling. The flow arrows 538 of FIG. 11A illustrate themultiple redundancies built into the stepped configuration 502.Depending on the configuration of the impermeable sections and thepermeable sections of the conduit-defining structural members, theincoming radial fluid flow may be redirected longitudinally and/orcircumferentially before exiting the flow control chamber. Theavailability of multiple outlets and flow paths from each chamber mayalso allow each flow control chamber to become more fully packed withinfiltrated sand.

The combination of FIGS. 11A and 11B illustrate what happens to the flowcontrol system in the stepped configuration when the inlet to the flowconduit is impaired and begins to allow sand to enter the flow conduit.As illustrated in FIG. 11B, the inlet 516 to the flow control chamber536 a is impaired due to erosion or other mechanical wear and a hole 540is opened in the wire-wrapped screen permitting the entry of sand 542into the flow control chamber 536 a. The sand 542 may begin toaccumulate against any one of the permeable sections 530 providing anoutlet 534. Due to the increased number of outlets and the ability ofthe flow to continue through one outlet while sand is accumulatingagainst another outlet, production through the flow control chamber 536a may continue at a higher rate and for a longer period of time.Additionally, as described elsewhere herein, the stepped configurationand the provision of multiple outlets and flow paths may contribute tothe formation of an internal natural sand pack by the infiltrated sandthat may allow the production of fluids to continue through flow controlchamber 536 a with reduced risk of sand infiltration into the productionflow control conduit 526 c. Still additionally, the steppedconfiguration 502 may promote prolonged production rates and prolongedproduction periods between workovers due to the proximity of theadjacent flow control chambers. As seen in FIG. 11B, when flow controlchamber 536 a is blocked or otherwise packed by sand, formation fluidsthat would otherwise enter chamber 536 a are able to be redirected, withcorresponding energy dissipation, to enter an adjacent flow controlchamber by traveling circumferentially around the outer member orlongitudinally along the outer member.

The above description provides numerous illustrations of flow controlsystems within the scope of the present invention. Each of the systemsare representative of the variety of systems that may be developedwithin the scope, teaching, and claims of the present invention.Moreover, it should be understood that each of the features of thevarious implementations may be interchangeable between the variousimplementations. For example, the selectively opening outlets describedin connection with FIGS. 6A-6F may be incorporated into any of the otherimplementations. The inlets and the outlets to the flow control chambersof the various implementations may be selectively opened in a variety ofmanners including, selective perforating, rupture disks,pressure-sensitive valves, sliding sleeves, RFID controlled flowdevices, etc. Additionally or alternatively, as described in connectionwith several implementations, the inlets and/or outlets may be adaptedto allow fluid communication while preventing sand infiltration in avariety of suitable manners, including wire-wrapped screen,perforations, mesh, varied-pitch wire-wrapped screens, etc., and may beprovided in any combination of filtration degrees, including filteringdifferent size particles, filtering similarly size particles, or both.

Additionally, as described in connection with FIG. 3, the flow controlsystems within the scope of the present disclosure may be assembled orconstructed in a variety of manners, including construction or assemblybefore insertion into the well and assembly after the components arealready run into the well. For example, the flow control systems may bemanufactured as standalone completion equipment ready to be coupled toother lengths of production or injection tubing. Additionally oralternatively, the flow control systems may include flow controlapparatus adapted to be run through production tubing that is alreadydisposed in the well. Inserting a flow control apparatus into an alreadydownhole tubular may be accomplished through the use of a variety ofavailable rig equipment and systems. Depending on the condition of thedownhole tubular and the configuration of the flow control apparatus,the tolerance between the flow control apparatus and the inner diameterof the tubular may vary. In some implementations, swellable material maybe disposed in a suitable manner on the flow control apparatus to closethe tolerances required during the running of the flow control apparatusinto position. The swellable material may be activated or swelled in anysuitable manner, such as practiced in other applications within theindustry. Additionally or alternatively, the tolerance between the flowcontrol apparatus and the inner diameter of the tubular member may besufficiently small to not require swelling material to seal between thetubular and the flow control apparatus. In some implementations, theflow control apparatus may not be intended to create a perfect sealbetween the apparatus and the tubular. For example, the configuration ofthe flow control apparatus, the flow control conduits, and the flowcontrol chambers may render the pressure loss between the apparatus andthe tubular sufficiently small that the fluid flow would be negligible.

The flow control systems of the present invention provide improvedprotection or countermeasures against a variety of flow impairmentmechanisms to allow operations to continue for a longer period of time.The redundant flow paths are adapted to allow operations to continueeven when a section of the well is impaired, such as by virtue of excesssand production, by virtue of scaling, or by virtue of blocked inlets.Similarly, the redundant sandscreens to prevent sand infiltration allowprolonged production from a section of the well when formation sand isbeing produced. By incorporating both redundant flow paths and redundantsandscreens, multiple flow impairment mechanisms are countered with asingle system, that in many implementations may be disposed in a welland allowed to respond autonomously without operator intervention.

In some implementations, the flow control conduits are adapted to directthe incoming fluids in a longitudinal direction before encountering achamber-defining structural member that changes the fluid's direction topass through an outlet. For example, the coaxial configuration of FIGS.5A and 5B promotes longitudinal flow in the outer flow control conduitbefore redirecting the flow radially to pass into the inner flow controlconduit. In other implementations, the flow control conduits are adaptedto direct the flow radially followed by a one or more directionalchanges either longitudinally or circumferentially before entering theproduction flow. Still additionally, in some implementations, theincoming flow through the inlet may be directed circumferentially and/orhelically (circumferentially and longitudinally) through on or more flowcontrol conduits before encountering a chamber-defining structuralmember changing the direction of the flow to cause the fluid to passthrough an outlet and into a production flow control conduit. Forexample, the multiple outlets of the stepped configuration describedherein allows fluid to flow both longitudinally within a flow controlchamber and circumferentially between flow control chambers beforepassing through an outlet into the production flow control conduit.Other implementations may include conduit-defining structural membersand/or chamber-defining structural members in any suitableconfiguration. As just one of the variety of examples, conduit-definingstructural members may be disposed helically around an inner tubular.The helically wrapped conduit-defining structural members may directflow helically around the inner tubular until encountering achamber-defining structural member that impedes the helical flow anddirects the flow through an outlet to the production flow controlconduit provided by the inner tubular. In some implementations, thechamber-defining structural members may be disposed transverse to thefluid flow direction imposed or encouraged by the flow control conduits.

Each of the implementations within the scope of the present inventionmay be adapted to suit a particular well or section of a well. Forexample, the number of flow control conduits and flow control chambersmay be varied as well as the length, width, depth, direction, etc. ofthe conduits and chambers. While the permutations of conduit-definingstructural members and chamber-defining structural members may beendless, engineers and operators may identify several that are moresuited for use due to one or more of ease of manufacture, ease of use,effectiveness in preventing sand production, effectiveness inmaintaining production rates, ability to customize configurations, etc.Each such permutation is within the scope of the present invention.

Example

The flow control systems of the present invention were demonstrated in alaboratory wellbore flow model. The laboratory wellbore model for theflow control system had a 25 centimeter (10-inch) OD, 7.6 meter(25-foot) Lucite pipe to simulate an open hole or casing. The apparatusto test the completion equipment was positioned inside the Lucite pipeand includes a series of three tubing sections. The three tubingsections consisted of 1) a flow control system having a mechanicallydamaged input region in the outer member, 2) a flow control systemhaving an intact input region in the outer member, and 3) a conventionalscreen having a mechanically damaged sandscreen. Each tubing section was15 centimeters (6 inches) in diameter and 1.8 meters (6-feet) long. Theflow control systems included a 91 centimeter (3-foot) long slottedliner and a 91 centimeter (3-foot) long blankpipe as the tubular orouter member. The flow control apparatus disposed within the flowconduits included a 7.5 centimeter (3-inch) OD, inner tubular(conduit-defining structural member), which consisted of a 1.2 meter(4-foot) long blankpipe and a 61 centimeter (2-foot) long wire-wrappedscreen. The outer member and the inner tubular in the modeled flowcontrol systems were concentric, following the exemplary coaxialconfiguration described above. During the test, water containing gravelsand was pumped into the annulus between the tubing assembly (completionsystem) and the Lucite pipe (open hole or casing).

The slurry (water and sand) first flowed through the annulus and intothe damaged flow control system. The sand entering the damaged flowcontrol system was retained and packed in the flow control chamberdefined between the inner tubular and the outer member. The growing sandpack increased the flow resistance and slowed down the sand entering thedamaged flow control system. As the sand entering the damaged flowcontrol system was diminishing, the slurry (water and sand) was divertedfurther downstream to the adjacent undamaged flow control system. Thegravel sand was packed in the annulus between the undamaged flow controlsystem and the Lucite pipe. Since this flow control system was intact,the sand was retained by the inlet in the outer member. As the undamagedflow control system was externally packed, the slurry was diverted tothe next damaged conventional screen. The sand flowed around and intothe damaged conventional screen. Since the conventional screen was notequipped with any secondary or redundant means for control sandinginfiltration, the sand continuously entered the eroded screen and couldnot be controlled.

The experiment illustrated the concepts of the flow control systemsduring the gravel packing portion of well completion operations. If partof the sand screen media is damaged during screen installation or erodedduring gravel packing operations, a flow control system as describedherein is able to retain gravel by secondary or redundant means tocounter sand infiltration or other flow impairment to thereby enablecontinuation of normal gravel packing operations. However, aconventional screen could not control gravel loss and would potentiallycause an incomplete gravel pack. The incomplete gravel pack with aconventional screen later causes formation sand production during wellproduction. Excessive sand production reduces well productivity, damagesdownhole equipment, and creates a safety hazard on the surface.

This experiment also illustrated the concepts underlying the flowcontrol systems of the present invention during well production ingravel packed completion or stand-alone completion. If part of thescreen media intended to prevent sand infiltration is damaged or erodedduring well production, a flow control system as described herein can 1)retain gravel or natural sand (e.g., formation sand) in the flow controlchambers of the flow control systems, 2) maintain the annular gravelpack or natural sand pack integrity, 3) divert flow to other intactscreens, and 4) continue sand-free production. In contrast, a damagedconventional screen will cause a continuous loss of gravel pack sand ornatural sand pack followed by continuous formation sand production.

While the present techniques of the invention may be susceptible tovarious modifications and alternative forms, the exemplary embodimentsdiscussed above have been shown by way of example. However, it shouldagain be understood that the invention is not intended to be limited tothe particular embodiments disclosed herein. Indeed, the presenttechniques of the invention are to cover all modifications, equivalents,and alternatives falling within the spirit and scope of the invention asdefined by the following appended claims.

1. A well flow control system comprising: a tubular adapted to bedisposed in a well to define a well annulus, wherein the tubular has anouter member defining an internal flow conduit, and wherein at least aportion of the outer member is permeable allowing fluid communicationbetween the well annulus and the flow conduit; and a flow controlapparatus adapted to be disposed within the flow conduit of the tubular,wherein the flow control apparatus comprises at least oneconduit-defining structural member and at least one chamber-definingstructural member; wherein the at least one conduit-defining structuralmember is configured to divide the flow conduit into at least three flowcontrol conduits; wherein the at least one chamber-defining structuralmembers is configured to divide at least two of the at least three flowcontrol conduits into at least two flow control chambers; wherein eachof the at least two flow control chambers has at least one inlet and atleast one outlet; wherein each of the at least one inlet and the atleast one outlet is adapted to allow fluids to flow therethrough and toretain particles larger than a predetermined size; and wherein at leastone of the at least three flow control conduits is in fluidcommunication with the well annulus only through one or more of the flowcontrol chambers.
 2. The well flow control system of claim 1, whereinthe flow control chambers in adjacent flow control conduits arefluidically offset and in fluid communication.
 3. The well flow controlsystem of claim 1, wherein fluid flow through an outlet of a flowcontrol chamber formed in a first flow control conduit passes into asecond flow control conduit.
 4. The well flow control system of claim 1,wherein the retention of particles larger than a predetermined size bythe outlet progressively increases resistance to flow through the outletfrom the flow control chamber until fluid flow through the outlet is atleast substantially blocked.
 5. The well flow control system of claim 1,wherein the at least two flow control chambers are disposed within theflow conduit of the tubular such that fluid flow entering through thepermeable portion of the outer member passes into at least one flowcontrol chamber.
 6. The well flow control system of claim 5, wherein theat least one inlet to the flow control chamber is provided by thepermeable portion of the outer member of the tubular.
 7. The well flowcontrol system of claim 1, wherein the at least one inlet to the flowcontrol chamber is adapted to retain particles of a first predeterminedsize and wherein the at least one outlet from the flow control chamberis adapted to retain particles of a second predetermined size.
 8. Thewell flow control system of claim 1, wherein the at least one inlet andthe at least one outlet of the flow control chamber are adapted toretain particles having at least substantially similar predeterminedsizes; and wherein the flow control chamber is adapted to progressivelyretain particles larger than the predetermined size of the at least oneoutlet in the event that the at least one inlet is impaired.
 9. The wellflow control system of claim 1, wherein the at least one inlet and theat least one outlet for at least one of the flow control chambers arefluidically offset and in fluid communication.
 10. The well flow controlsystem of claim 1, wherein the flow within at least one of the flowcontrol chambers is at least substantially longitudinal; and wherein theat least one chamber-defining structural member is disposed at leastsubstantially transverse to the longitudinal direction.
 11. The wellflow control system of claim 1, wherein the flow within at least one ofthe flow control chambers is at least substantially circumferential; andwherein the at least one chamber-defining structural member is disposedat least substantially transverse to the circumferential direction. 12.The well flow control system of claim 1 wherein each of the at least oneoutlets is adapted to be selectively opened to control fluid flowthrough the outlet.
 13. The well flow control system of claim 1 whereinat least one of the at least two flow control chambers includes at leasttwo outlets, wherein each of the at least two outlets is adapted toretain particles of different predetermined sizes, and wherein each ofthe at least two outlets is adapted to be selectively opened to fluidflow to selectively retain particles of different predetermined sizesdepending on which outlet is opened.
 14. The well flow control system ofclaim 1 wherein the inlet to at least one flow control chamber is formedin the flow control apparatus; and wherein the outlet from the at leastone flow control chamber is formed by the permeable portion of the outermember.
 15. The well flow control system of claim 1 wherein thepermeable portion of the outer member provides an inlet to at least oneflow control chamber; and wherein the outlet from the at least one flowcontrol chamber is formed in the flow control apparatus.
 16. The wellflow control system of claim 1 wherein the flow control apparatus isadapted to be run in a tubular disposed in a well.
 17. (canceled) 18.The well flow control system of claim 1 wherein the at least oneconduit-defining structural member is adapted to provide at least onenon-permeable diversion surface one or more of the flow controlchambers, wherein the non-permeable diversion surface is disposed in adirect fluidic path of the inlet to the flow control chamber such thatincoming fluid is diverted.
 19. The well flow control system of claim 18wherein each flow control chamber includes at least two outlets each ofwhich are fluidically offset from the inlet.
 20. The well flow controlsystem of claim 19 wherein each of the at least two outlets providesfluid communication with a different flow control conduit.
 21. A flowcontrol apparatus adapted for insertion into a flow conduit of a welltubular, the flow control apparatus comprising: at least oneconduit-defining structural member adapted to be inserted in a flowconduit of a well tubular and to divide the flow conduit into at leastthree flow control conduits; at least two chamber-defining structuralmember configured to divide at least two of the at least three flowcontrol conduits into at least two flow control chambers; and at leastone permeable region provided in at least one of the at least oneconduit-defining structural member and the at least two chamber-definingstructural members; wherein the at least one permeable region is adaptedto allow fluid communication and to retain particles larger than apredetermined size; wherein fluids flowing through the at least onepermeable region pass from a first flow control conduit to a second flowcontrol conduit within the flow conduit; and wherein at least one of theat least three flow control conduits is adapted to be in fluidcommunication with a well annulus only through one or more of the flowcontrol chambers.
 22. The flow control apparatus of claim 21 wherein theflow control apparatus is adapted to be run into a well tubular disposedin a well.
 23. The flow control apparatus of claim 21 further comprisingswellable materials disposed at least on the at least oneconduit-defining structural member and adapted to at least substantiallyseal against the well tubular to fluidically isolate the at least twoflow control conduits from each other such that flow between flowcontrol conduits occurs at least substantially only through the at leastone permeable region.
 24. (canceled)
 25. The flow control apparatus ofclaim 21 wherein the at least one permeable region is adapted to beselectively opened to control the particle size being filtered from theflow through the permeable region.
 26. The flow control apparatus ofclaim 21, wherein the flow control chambers in adjacent flow controlconduits are fluidically offset and in fluid communication.
 27. The flowcontrol apparatus of claim 21, used in a method to control particulateflow in hydrocarbon well equipment, the method comprising: providing atubular adapted for downhole use in a well, wherein the tubularcomprises an outer member defining a flow conduit, and wherein at leasta portion of the outer member is permeable and allows fluid flow throughthe outer member; providing at least one flow control apparatuscomprising: a) at least one conduit-defining structural member adaptedto be disposed in the flow conduit of the tubular and to divide the flowconduit into at least three flow control conduits; and b) at least twochamber-defining structural member configured to divide at least two ofthe at least three flow control conduits into at least two flow controlchambers; disposing the tubular in a well; disposing the at least oneflow control apparatus in the well; operatively coupling the at leastone flow control apparatus with the tubular; wherein the operativelycoupled tubular and at least one flow control apparatus comprise the atleast three flow control conduits and the flow control chambers; whereineach of the flow control chambers has at least one inlet and at leastone outlet; wherein each of the at least one inlet and the at least oneoutlet is adapted to allow fluids to flow therethrough and to retainparticles larger than a predetermined size; and flowing fluids throughthe at least one flow control apparatus and the tubular.
 28. The methodof claim 27 wherein the permeable portion of the outer member providesat least one inlet to at least one flow control chamber; and whereinflowing fluids through the at least one flow control apparatus and thetubular comprises flowing production fluids through the permeableportion of the outer member and through the outlets of the flow controlchambers to produce hydrocarbons from the well.
 29. The method of claim27 further comprising operatively coupling the at least one flow controlapparatus and the tubular before disposing said at least one flowcontrol apparatus and the tubular in the well.
 30. The method of claim27 wherein flowing fluids through the at least one flow controlapparatus and the tubular comprises: flowing fluid into at least oneflow control chamber disposed in a first flow control conduit through atleast one inlet, wherein the fluid flows through the at least one inletin a first flow direction; redirecting the fluid within the flow controlchamber to flow in a second flow direction; and redirecting the fluidwithin the flow control chamber to flow in a third flow direction topass through the at least one outlet and into a second flow controlconduit.
 31. The method of claim 30 wherein the second flow direction isat least one of substantially longitudinal, circumferential, radial, andhelical. 32-34. (canceled)
 35. The method of claim 27 wherein flowingfluids through the at least one flow control apparatus and the tubularcomprises injecting at least one of stimulation fluids, produced fluids,drilling fluids, completion fluids, and gravel pack fluids into thewell. 36-39. (canceled)